Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
197-217
A • y OF Tye, • �w\,,„jam s, THE STATE Alaska Oil and Gas ��►�:'���, ofLAsKA. Conservation Commission St ^- 333 West Seventh Avenue � GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 p "*'�"P- Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov December 5, 2017 Mr. Patrick Wolfe North Slope Operations Manager ConocoPhillips Alaska, Inc. • P. O. Box 100360 Anchorage, AK 99510-0360 Re: Docket Number: OTH 17-045 SC004E Defeated Safety Valve System KRU 1D-124 (PTD 1972170) Dear Mr. Wolfe: The Alaska Oil and Gas Conservation Commission (AOGCC) reviewed ConocoPhillips Alaska Inc (CPAI)'s November 22, 2017, explanation regarding the defeated safety valve system on Kuparuk River Unit 1D-124. CPAI presented the findings from its internal investigation and corrective actions that have been implemented to prevent recurrence of defeated well safety valve systems at CPAI-operated wells within Alaska. These actions address the concerns identified in the violation. The AOGCC does not intend to pursue any further enforcement action regarding the Kuparuk River Unit 1D-124 defeated safety valve system. Sincerely, odA2rC ___ Hollis S. French Chair, Commissioner cc: AOGCC Inspectors (via email) rick Wolfe Manager North Slope Integrated Operations and Projects ConocoPh i Hips• Post Office Box 100360 Anchorage,Alaska 99510 ATO-1226 Phone 907.265.6202 Patrick.J.Wolfe@conocophillips.com November 22,2017 Hollis S. French RECEIVED Chair, Commissioner NOV z Z 2011 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue ����^ Anchorage,AK 99501-3572 1'„� Dear Commissioner French: Re: Response to AOGCC for the KRU 1D-124 Defeated Safety Value System (SVS) On November 5, 2017,the wellhead safety valve system (SVS)was found to be defeated during a required performance test of the 1D-124 well in the Kuparuk River Unit(KRU). ConocoPhillips Alaska (COPA) started an investigation of the matter on the same day. In a letter received November 10,2017,the AOGCC asked COPA to provide the Commission with an explanation of how this event happened and what has been or will be done in the future to prevent recurrence. COPA provides the following description of events that led to the wellhead SVS being defeated,as revealed by our incident investigation,and steps being taken to prevent recurrence. Description of Incident: During a State witnessed SVS test on well 1D-124,the exhaust port valve for the Bettis SSV actuator was found to be blocked, preventing discharge of the hydraulic pressure,thus holding the surface safety valve (SSV) open. When the valve was opened,the pressure released and allowed the SSV to close. Contrary to COPA policy and Alaska Safety Handbook requirements,there was no flagging or tag present on the valve to indicate that it was in the closed position, and there was no entry to the Safety Defeat Log to record that the low-pressure pilot was in a defeated condition. The orange Operations custody seal was on the valve, indicating(incorrectly)that Operations had confirmed it was in its normal position. Hollis S. French Chair, Commissioner,AOGCC November 22, 2017 Page 2 Findings: COPA completed an investigation into the defeated SVS on November 8, 2017 with the following findings: After completion of the rig workover on well 1D-124,the wellhead piping and Surface Safety Valve (SSV) were assembled,functionally checked out(FCO),and turned over to operations on November 2, 2017. The SSV was functionally tested during this process by both the Drill Site Operator and the FCO Instrument Technician prior to well start up. Both functional tests confirmed the stroke of the SSV to the closed position. The investigators found that the hydraulic actuator exhaust valve on the SSV actuator was closed sometime after the FCO was completed and when the SSV was found defeated during the AOGCC witnessed performance test on 11/5/17. The investigation did not determine exactly when the valve was closed, but it is assumed to have been during the initial well start up on November 2, 2017. Startup of an ESP well is typically done in a deliberate manner to avoid inadvertent ESP shutdowns or upsets as these can cause pump damage that could require another rig workover. It is likely that the SSV was defeated by closing the actuator exhaust valve during this time of manned operation and well stabilization,and that the SSV actuator exhaust port valve was then inadvertently left in this condition upon successful well startup. The SSV was serviced by the Valve Crew the first evening after initial startup. The SSV was not stroked during this service operation to avoid interruption of the ESP operation. The actuator exhaust valve was not touched as part of this service. The closed valve was not noticed during the daily operator wellhouse inspections that were completed each of the days during that period prior to the State witnessed test on the third day. Operator logs do not indicate that any other work was done on the well during that time. The valve handle location and shape of the actuator exhaust valve made it more difficult to custody seal and visually harder to distinguish the valve orientation. The Operations custody seal was only loosely affixed to the valve and would have allowed the valve to be closed without removing the seal. There are only 35 wells in the Kuparuk field with similar SSV's with Bettis actuators, so operational experience with these valves is limited. Hollis S. French • • • Chair, Commissioner,AOGCC November 22, 2017 Page 3 Response: In response to this discovery of a closed valve,we immediately inspected the wellhead SVS on each similar well in KRU for proper alignment and custody seals. All wells were found to be correctly aligned with the correct seals. Our investigation into this matter has revealed this was a human error. In addition to inspecting similar KRU wellhead SVS systems for proper valve alignment,which has been done, we are committed to complete the following work in response to this incident: • Prepare a field-wide bulletin,alerting personnel to this error and reminding them of the expectations in ensuring compliance with the Safety Valve System Operating Procedure. • Review and reinforce the Alaska Safety Handbook Tagging and Flagging Standard, and daily well walk requirements with drill site managers and operators throughout the KRU. Note that KRU had recently commissioned a team to establish clear and consistent well walk requirements and expectations for Drill Site Operators, but had not completed this effort at the time of this incident. This will be completed and communicated to operations staff. • Develop and implement improved training material for this specific SSV with Bettis actuator configuration. • Continue the management wellhead SVS audit program that was recently implemented in 3Q 2017. • Continue to implement improvements to the SVS Operating Procedure as improvements are identified. Yours truly, i _ , �IV 1 V ' Patrick Wolfe OTH-17-045 • • Notice of Violation—KRU 1D-124 November 7,2017 Page 2 of 2 The AOGCC reserves the right to pursue enforcement action in connection with the defeated safety valve system on KRU 1D-124. Questions regarding this letter should be directed to Jim Regg at 907-793-1236. Sincerely, tom. 2CcA__ Hollis French Chair, Commissioner Attachment cc: P. Brooks AOGCC Inspectors RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a),within 20 days after written notice of the entry of this order or decision,or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration of the matter determined by it. If the notice was mailed,then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10-days is a denial of reconsideration. If the AOGCC denies reconsideration,upon denial,this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the AOGCC mails,OR 30 days if the AOGCC otherwise distributes,the order or decision denying reconsideration,UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the AOGCC grants an application for reconsideration,this order or decision does not become final. Rather,the order or decision on reconsideration will be the FINAL order or decision of the AOGCC,and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the AOGCC mails,OR 30 days if the AOGCC otherwise distributes,the order or decision on reconsideration. In computing a period of time above,the date of the event or default after which the designated period begins to run is not included in the period;the last day of the period is included,unless it falls on a weekend or state holiday,in which event the period runs until 5:00 p.m.on the next day that does not fall on a weekend or state holiday. • 1110 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg l s� ' -I DATE: 11/5/17 P. I. Supervisor FROM: Matt Herrera SUBJECT: Defeated SVS Petroleum Inspector KRU 1D-124 r PTD 1972170 On Nov. 5, 2017 I traveled to Kuparuk for SVS testing and met up with well testers Brian Martin and Danny Rotondo. Well KRU 1D-124 is an ESP completion and had been brought online 11/2/17. The low pressure pilot setpoint is 70 psi with a flowing tubing pressure of 166 psi. They started to bleed off the pressure to test the low pressure pilot, and at a reading of 50 psi the tester paused to ensure correct valve alignment and connection onto correct pilot switch. It was then discovered the low pressure pilot for the tubing/flowline was tie wrapped in the "CLOSED" position disabling the pilot and SSV from operation. The valve was then opened, and all other valve alignment verified for correct operation. The retest went without any failures once the low pressure pilot was put in service and the well was left online. CPAI noted they would conduct their own investigation of cause and mitigation of another like incident. Attachments: None Non-Confidential 2017-1105 SVS KRU_ID-124 defeated mh.docx Page 1 of 1 or hw \ I%%/', THE STATE Alaska Oil d Gas Fof LAsKA Conservation Commission 34fitt =_ 333 West Seventh Avenue —� Anchorage, Alaska 99501-3572 � � GOVERNOR BILL WALKER g �h',> Main: 907.279.1433 ALAS"' Fax: 907.276.7542 www.aogcc.alaska.gov November 7, 2017 CERTIFIED MAIL— RETURN RECEIPT REQUESTED 7015 1660 0000 1487 7487 Mr. Patrick Wolfe North Slope Operations Manager ConocoPhillips Alaska, Inc. P. O. Box 100360 Anchorage, AK 99510-0360 Re: Docket Number: OTH-17-045 Defeated Safety Valve System KRU 1D-124 (PTD 1972170) Dear Mr. Wolfe: On November 5, 2017, an Alaska Oil and Gas Conservation Commission (AOGCC) Inspector witnessed miscellaneous well safety valve system tests on Kuparuk River Unit(KRU) 1D pad that were performed by a ConocoPhillips Alaska Inc (CPAI) representative. The safety valve system on KRU 1D-124 was found defeated. Investigation revealed that the safety valve system was defeated with the sensing line block valve tie-wrapped in the closed position. A copy of the Inspector's report is attached. The facts reported by the AOGCC Inspector indicate a failure to maintain an operable safety valve system which is a violation of State regulations. CPAI is reminded that a completed well must be equipped with a functional safety valve system as described in 20 AAC 25.265. Paragraph(m)of 20 AAC 25.265 establishes tagging procedures for a well safety valve system component that is inoperable, removed, or blocked. There was neither a tag observed on KRU 1D-124 that would indicate an inoperable safety system nor was there any reason for the valve to be defeated. Defeating any component of the critical well safety valve system—except as provided in 20 AAC 25.265 —will not be tolerated. Within 14 days of receipt of this letter, you are requested to provide the AOGCC with a copy of its internal investigation report, and describe what has or will be done in the future to prevent its recurrence at CPAI-operated fields in Alaska. Failure to comply with this request will be an additional violation. U.S. Postal Service!" CERTIFIED MAIL° RECEIPT P" Domestic Mail Only ca For delivery information.visit our website at www.usps.com'. N ED Certified Mail Fee $ r'-1 Extra Services&Fees(check box,add fee as appropriate) ❑Return Receipt(hardcopy) Postmark 0 0 Return Receipt(electronic) $ ❑Certified Mail Restricted Delivery $--- Here ❑Adult Signature Required $--0 Adult Signature Restricted Delivery$- -- Postage $ Total Post Mr. Patrick Wolfe $ North Slope Operations Manager u9 Sent To ra ConocoPhillips Alaska, Inc. sveetand P. 0. Box 100360 City State Anchorage, AK 99510-0360 t1-'��it��'irk=�TJ1�'ZiSF�iibid3ikaiLQrII-TiLY��.Za-a:t:�tat--t:at�r.rt�u.rh"i'�'7 t SENDER: COMPLETE THIS SECTION COMPLETE THIS SECTION ON OELII'ERY � , • Complete items 1,2,and•3.• A. Signature f` „,Agent • Print your name and address on the reverse X so that we can return the card to you. are 0 Addressee ■ Attach this card to the back of the mailpiece, B. ReReived by(Pint -,/e) 7 C. Date of Delivery or on the front if space permits. �Gait/ i c175 1. Article Addressed to: ,07"1.4 -/')-Q 1-/5 D. Is delivery address different from item 1? ❑Yes If YES,enter delivery address below: ®No Mr. Patrick Woffe North Sites Operations Manager ConocoPhillips Alaska, Inc. NOV 1 3 2017 P. O. Box 100360 Anchorage, AK 99510-0360 3. Service Type k'L4 1/4- ❑Priority Mai Express® II I f' 1111 111111 1111 11 I 111111 11111 0 Adult Signature 0 Registered Delivery MTm Adult inrRestricted Delivery 0 Registered ail Restricted ❑Certified Mail® 9590 9402 1823 6104 6487 02 0 Certified Mail Restricted Delivery 0 Return Receipt for 0 Collect on Delivery Merchandise 2. Article Number(Transfer from service label) 0 Collect on Delivery Restricted Delivery 0 Signature ConfirmationTM I Mail 0 Signature Confirmation 7 015 1660 0000 1487 7487 Mail Restricted Delivery Restricted Delivery ;00) PS Form 3811,July 2015 PSN 7530-02-000-9053 Domestic Return Receipt ,_ . . _. _____. e • s —r 0 CI ¢ " � ca 0 0 "4 b c. -a-) o N CD Cf) �Q. o • o �; .cG o: U ` 0RC Co a b o r:4 a T. O.— O O O •v x (� V ' y '' ziz zcy N o Cz z z c xca w — C Lao O ,o ,D H ~ u o aLi � = a � o � ' 3 "' 0 I $....464 . O d O a VD c a VD ,..0 0v I n CI) > v - L z ti7 ca co � U C7 I C7 � r-� a m '' 3 ¢ 3 3 YN ct Q O C7 f ania ql � 03 c" 1 .a OU � r cub O °E= 2zzi _U . oVI 4.c a ... C)(a a. a C 67 V O N \ elJ RL aU0. G G E-t` O zi O I. C N V 1 A v, a 0 VI Op i OO O Or N N VI C1 1.0 W a I 1- i ,,/W 11' oo N• a ^ Pr 1- P �LO, 0a g. ,/ A o ,ti F ti --i °' z aC � z Q Q�6 fi CD o civ 0 0 a w 3 RECEIVED STATE OF ALASKA AKA OIL AND GAS CONSERVATION COM SION NOV 2 1. 2017 REPORT OF SUNDRY WELL OPERATIONS AOGCC 1.Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing 0 Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ 'erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: ESP MOTOR Li 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development 0 Exploratory❑ 197-217 3.Address: P. O. Box 100360,Anchorage,Alaska Stratigraphic❑ Service ❑ 6.API Number: 99510 50-029-22833-00 7.Property Designation(Lease Number): 8.Well Name and Number: KRU 1D-124 ADL 25650 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Kuparuk River Field/West Sak Oil Pool 11.Present Well Condition Summary: Total Depth measured 5,047 feet Plugs measured None feet true vertical 4,263 feet Junk measured None feet Effective Depth measured 4,905 feet Packer measured 2,507 feet true vertical 4,128 feet true vertical 2,236 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 feet 16 " 121'MD 121 PRODUCTION 4,993 feet 7 5/8" 5,033' MD 4250 Perforation depth Measured depth 4356-4388,4420-4484,4514-4560,4590-4672 feet TrueVertical Depth 3613-3643,3673-3733,3761-3804,3832-3909 feet Tubing(size,grade,measured and true vertical depth) 3.5 " L-80 4,256'MD 3,520'TVD Packers and SSSV(type,measured and true vertical depth) PACKER-ESP FEED-THRU PACKER,WEATHERFORD HYDROW II DUAL-STRING PACKER 2,507' MD 2,236'TVD SSSV: -NONE 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A %GWED OE , 2 8. 2.1 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: SHUT-IN 0 0 0 0 Subsequent to operation: 127 98 188 159 169 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations I] Exploratory ❑ Development I] Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil 0 Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Name: Ron Phillips • Authorized Name: Ron Phillips Contact Email: Ron.L.Phillips@cop.com Authorized Title: Sr.Wells Engineer Authorized Signature: 72gh V. Date: 11!/21/30i7 Contact Phone: (907)265-6312 I vrt, /2-/7--/I.7 A' /;-/77 R :1'3 LU ,. 2 'Y. 207 Form 10-404 Revised 4/2017 Submit Original Only • • • Operations Summary (with Timelog Depths) 0 1D-124 coPhitliips Rig: DOYON 14 Job: RECOMPLETION Time Log Start Time End Time Our(hr) PhaseStart Depth Op Code Activity Code 7�me P-T-X Operation (EKE) End Depth(ftKB) 10/21/2017 10/21/2017 0.75 MIRU MOVE RURD P Prep to skid the rig floor. Pin the 0.0 0.0 16:00 16:45 beaver slide into move position. 10/21/2017 10/21/2017 0.25 MIRU MOVE SFTY P AAR with rig crew on RU and testing 0.0 0.0 16:45 17:00 the tubing/tree with LRS. 10/21/2017 10/21/2017 1.00 MIRU MOVE RURD P PJSM. Skid the rig floor into moving 0.0 0.0 17:00 18:00 position. 10/21/2017 10/21/2017 1.50 MIRU MOVE MOB P Move the rig off well 1C-102 and stage 0.0 0.0 18:00 19:30 on the pad to install boosters. 10/21/2017 10/21/2017 1.25 MIRU MOVE RURD P PJSM. Install the rear booster wheels. 0.0 0.0 19:30 20:45 10/21/2017 10/21/2017 2.00 MIRU MOVE RURD P Install the front booster wheels. 0.0 0.0 20:45 22:45 10/21/2017 10/22/2017 1.25 MIRU MOVE MOB P Move the rig 1.5 miles down 1C 0.0 0.0 22:45 00:00 access road to KIC access road. Move onto the KIC access road and move towards the spine road. 10/22/2017 10/22/2017 1.50 MIRU MOVE MOB P Continue to move down KIC access 0.0 0.0 00:00 01:30 road to the spine road. 10/22/2017 10/22/2017 1.00 MIRU MOVE MOB P Take a right on the spine road and 0.0 0.0 01:30 02:30 turn the rig around in front of the big white tent on KCC pad. 10/22/2017 10/22/2017 2.00 MIRU MOVE MOB P Move the rig 2.8 miles from KCC pad 0.0 0.0 02:30 04:30 to 1D pad and stage in the center of the pad. 10/22/2017 10/22/2017 0.75 MIRU MOVE RURD P PJSM. Remove front booster wheels. 0.0 0.0 04:30 05:15 10/22/2017 10/22/2017 1.75 MIRU MOVE RURD P Remove front booster wheel support 0.0 0.0 05:15 07:00 frame"Star Wars"and reinstall the front stairs. 10/22/2017 10/22/2017 1.00 MIRU MOVE RURD P PJSM. Remove rear booster wheels. 0.0 0.0 07:00 08:00 10/22/2017 10/22/2017 2.00 MIRU MOVE MOB P Move the rig over well 1D-124. Center 0.0 0.0 08:00 10:00 and shim the rig. 10/22/2017 10/22/2017 1.00 MIRU MOVE RURD P PJSM. Skid the rig floor into drilling 0.0 0.0 10:00 11:00 position. 10/22/2017 10/22/2017 4.00 MIRU MOVE RURD P Install the handrails and stairs. Unpin 0.0 0.0 11:00 15:00 and set the beaver slide. Housekeeping around the rig. Extend #2 conveyor. RU the mud lines and steam to the rig floor. Spot the snack shack,mud shack,supply connex and cuttings tanks. 10/22/2017 10/22/2017 1.00 MIRU MOVE RURD P Rig up circulating lines in the cellar. 0.0 0.0 15:00 16:00 Rig accepted at 16:00 hours. 10/22/2017 10/22/2017 2.50 MIRU WELCTL MPSP P RU the lubricator,pull the BPV and 0.0 0.0 16:00 18:30 RD the lubricator. Tubing=600 psi and IA=575 psi. SimOps: Started loading the pits with 225 bbls of 8.5 ppg seawater at 17:00 hours. 10/22/2017 10/22/2017 1.50 MIRU WELCTL SEQP P Blow air through the circulating lines to 0.0 0.0 18:30 20:00 the kill tanks. Fill the lines with fresh water and PT lines to 3000 psi. Small leak on 2"high pressure hose. SimOps: Take on 11.6 ppg brine from the upright tank to the vac truck. Page 1/7 Report Printed: 10/31/2017 • • Operations Summary (with Timelog Depths) `4,4i* 1D-124 CorK3coPhillips Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftK6) End Depth(ftKE) 10/22/2017 10/22/2017 0.50 MIRU WELCTL RGRP T Bleed off the pressure and blow down 0.0 0.0 20:00 20:30 the line. Change out the 2"high pressure hose. SimOps: Take on 11.6 ppg brine from the upright tank to the vac truck. 10/22/2017 10/22/2017 0.25 MIRU WELCTL SEQP T PT lines to 3000 psi(good test). 0.0 0.0 20:30 20:45 SimOps: Take on 11.6 ppg brine from the upright tank to the vac truck. 10/22/2017 10/22/2017 1.00 MIRU WELCTL RURD P RU the rig floor. 0.0 0.0 20:45 21:45 SimOps: Load the pits with 290 bbls of 11.6 ppg NaCl/NaBr brine. 10/22/2017 10/22/2017 2.00 MIRU WELCTL COND P Mix the seawater and 11.6 ppg brine 0.0 0.0 21:45 23:45 in the pits until all pits have a fluid weight of 10.2 ppg NaCl/NaBr. SimOps: General housekeeping. 10/22/2017 10/23/2017 0.25 MIRU WELCTL SFTY P PJSM on the well kill operation. 0.0 0.0 23:45 00:00 10/23/2017 10/23/2017 1.50 MIRU WELCTL KLWL P Open the IA,bleed off the gas and 0.0 0.0 00:00 01:30 close the IA. Open the tubing,bleed off the gas and close the tubing. Reverse circulate 186 bbls 10.2 ppg NaCI/NaBr brine down the IA taking returns up the tubing at 3 BPM=325 psi holding 200 psi back pressure at the choke. Got 10.2 ppg brine at surface,shut down the pumps and shut in the well. The kill tank had 176 bbls. 10/23/2017 10/23/2017 0.25 MIRU WELCTL KLWL P Line up to bullhead. Bullhead 26 bbls 0.0 0.0 01:30 01:45 of 10.2 ppg brine down the tubing at 3 BPM=625 psi. 10/23/2017 10/23/2017 0.25 MIRU WELCTL RURD P Blow down circulating lines to the kill 0.0 0.0 01:45 02:00 tank. 10/23/2017 10/23/2017 0.75 MIRU WELCTL OWFF P Open the well up to pressure gauges. 0.0 0.0 02:00 02:45 Tubing=0 psi and IA=0 psi. Open the tubing and IA to buckets in the cellar. Observe the well for flow for 30 minutes and the well is static. 10/23/2017 10/23/2017 0.25 MIRU WELCTL RURD P Blow down the injection line and RD 0.0 0.0 02:45 03:00 circulating lines in the cellar. 10/23/2017 10/23/2017 0.25 MIRU WHDBOP MPSP P Install HP BPV with dry rod. 0.0 0.0 03:00 03:15 SimOps: Continue to RD circulating lines. 10/23/2017 10/23/2017 0.50 MIRU WHDBOP FRZP P Fluid pack the hard line to the kill tank 0.0 0.0 03:15 03:45 with diesel. 10/23/2017 10/23/2017 1.00 MIRU WHDBOP NUND P PJSM. Bleed of the tubing hanger 0.0 0.0 03:45 04:45 void. ND the tree and tubing head adapter. Install the plug off tool into the BPV. 10/23/2017 10/23/2017 0.75 MIRU WHDBOP NUND P Clean the wellhead and place packing 0.0 04:45 05:30 around the penetrators. 10/23/2017 10/23/2017 5.00 MIRU WHDBOP NUND P NU 11"x 13-5/8"DSA,NU 13-5/8" 0.0 0.0 05:30 10:30 spacer spool and NU the BOP stack. NU the kill line and install the riser. Page 2/7 Report Printed: 10/31/2017 • 0 Operations Summary (with Timelog Depths) 0 0 Fay, 1D-124 ConooriPhitl ass Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth MKS)' 10/23/2017 10/23/2017 0.75 MIRU WHDBOP RURD P RU BOPE testing equipment. 0.0 0.0 10:30 11:15 10/23/2017 10/23/2017 4.00 MIRU WHDBOP BOPE P Conduct initial BOPE test: test 3-1/2" 0.0 0.0 11:15 15:15 x 6"VBR's(upper pipe rams)to 250/2500 psi with 3-1/2"test joint;test 3-1/2"x 6"VBR's(lower pipe rams)to 250/2500 psi with 3-1/2"test joint;test annular to 250/2500 with 3-1/2"test joint;conducted Koomey drawdown test(all tested passed). The states right to witness was waived by AOGCC inspector Jeff Jones via phone conversation on 10/22/17 at 17:08 hours. Tests: 1) 3-1/2"x 6"VBR's(lower pipe rams) with 3-1/2"test joint(Passed) 2) Annular with 3-1/2"test joint,upper IBOP,3"Demco,choke valves, 12, 13 &14(Passed) 3) 3-1/2"x 6"VBR's(upper pipe rams)with 3-1/2"test joint,lower IBOP,kill HCR,choke valves 9&11 (Passed) 4) Manual kill,choke valves 5,8&10 (Passed) 5) 4"HT-38 FOSV,choke valves 4,6 &7(Passed) 6) 4"HT-38 dart valve,choke valve 2 (Passed) 7) Blind rams,3-1/2"EUE 8rd FOSV, choke valves 1 &3(Passed) 8) Manual choke(Passed) 9) Super choke(Passed) 10) Choke HCR(Passed) 11) Manual choke(Passed) Conduct Koomey Draw Down Test: Starting Accumulator Pressure=3050 psi Accumulator Pressure After Closer= 1750 psi Pressure Gain of 200 psi=44 seconds Full System=196 Seconds Average N2(6 Bottles)=2087 psi 10/23/2017 10/23/2017 1.00 MIRU WHDBOP RURD P RD BOPE testing equipment. Blow 0.0 0.0 15:15 16:15 down the choke and kill lines. Blow down the choke manifold and drain the BOP stack. 10/23/2017 10/23/2017 0.25 MIRU WHDBOP MPSP P PJSM. MU the dry rod and pull the 0.0 0.0 16:15 16:30 plug off tool. Check for pressure under the BPV and gas was observed. 10/23/2017 10/23/2017 0.50 MIRU WHDBOP RURD T RU to circulate out to the kill tank. 0.0 0.0 16:30 17:00 Suspend 3rd party operations near the flow back tank. 10/23/2017 10/23/2017 0.50 MIRU RPCOMP CIRC T Circulate down the tubing up the IA to 0.0 0.0 17:00 17:30 the flow back tanks at 1 BPM=200 psi(ICP). It took 5 bbls pumped to get returns,at 8 bbls lost returns and at 10 bbls had returns again. At 23 bbls pump pressure dropped to 80 psi. Pumps off at 24 bbls pumped. Page 3/7 Report Printed: 10/31/2017 • S Operations Summary (with Timelog Depths) ,4-4244V-- ", ' 10-124 ConcicoPhillips Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/23/2017 10/23/2017 0.25 MIRU RPCOMP OWFF T Observe the well for flow and the 0.0 0.0 17:30 17:45 tubing is on a vac. Open the blind rams and close the kill line. 10/23/2017 10/23/2017 0.25 MIRU WHDBOP MPSP P Pull the BPV and install the side port 0.0 0.0 17:45 18:00 isolation sleeve with the dry rod. 10/23/2017 10/23/2017 0.50 COMPZN RPCOMP RURD P MU the landing joints with crossovers 0.0 0.0 18:00 18:30 back to 4"HT-38 and MU the top drive. 10/23/2017 10/23/2017 0.50 COMPZN RPCOMP PULL P Close the annular and BOLDS. 0.0 4,245.0 18:30 19:00 Unseat the tubing hanger at 80K and continue to PU to 160K to shear the Weatherford packer. 10/23/2017 10/23/2017 0.25 COMPZN RPCOMP CIRC P IA and tubing on a vac. Open the 4,245.0 4,245.0 19:00 19:15 annular. Circulate at 3 BPM=50 psi getting crude to surface. At 14 bbls pumped a leak at the auger box spilled 1 gallon of wellbore fluid onto the rig cellar containment. Pumps off. The spill was cleaned up with absorb and properly disposed of. 10/23/2017 10/23/2017 1.00 COMPZN RPCOMP CIRC P Line up to take returns to the kill tank. 4,245.0 4,245.0 19:15 20:15 Circulate 160 bbls down the tubing taking returns up the IA to the kill tank at 3 BPM(ICP=60 psi and FCP= 250 psi). 10.2 ppg brine in/out. 10/23/2017 10/23/2017 0.50 COMPZN RPCOMP OWFF P Observe the well for flow and no flow. 4,245.0 4,245.0 20:15 20:45 Blow down the lines to the kill tank. 10/23/2017 10/24/2017 3.25 COMPZN RPCOMP RURD P RU the ESP cable sheave and 4,245.0 4,245.0 20:45 00:00 elephant trunk. String rope through the sheave and elephant trunk to the spooling unit. SimOps: Continue to monitor the well. Tubing=3 psi and IA=60 psi. 10/24/2017 10/24/2017 1.00 COMPZN RPCOMP KLWL P Open the IA to the flow back tank and 4,245.0 4,245.0 00:00 01:00 flow back 13 bbls of crude. Circulate 106 bbls of 10.2 ppg brine down the tubing up the IA to the kill tank at 3 BPM(ICP=120 psi and FCP=230 psi). Ran out of fluid,pumps off and shut in the IA. 10/24/2017 10/24/2017 5.50 COMPZN RPCOMP KLWL P Wait for additional fluid to arrive. 4,245.0 4,245.0 01:00 06:30 SimOps: Blow down the line to the kill tank.General housekeeping. Monitor the well pressures. 10/24/2017 10/24/2017 0.50 COMPZN RPCOMP KLWL P Attempt to land tubing hanger.Tag up 4,245.0 4,245.0 06:30 07:00 26.5'in on landing joint.PU=105K Slack off to 40K.Unable to land hanger.Sin-ops/Take on 290 bbls 10.2 ppg brine. 10/24/2017 10/24/2017 3.00 COMPZN RPCOMP KLWL P PJSM-Rig up to circulate/reverse 4,245.0 4,245.0 07:00 10:00 circulate to flowback tank.Test lines to 1000 psi.Suspend 3rd party operations near flow back tanks. Attempt to land hanger.PU=95K Slack off to 40K. Unable to land hanger. Page 4/7 Report Printed: 10/31/2017 • • Operations Summary (with Timelog Depths) 00106 C.4 10-124 itot Cor ocxe'"tsiiiiips Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time` End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation {ftK€B> End Depth(ftKE) 10/24/2017 10/24/2017 2.00 COMPZN RPCOMP RURD P Verify IA and tbg at 0 psi.Open 4,245.0 4,245.0 10:00 12:00 annular preventer.Monitor well.Fill hole w/9 bbls 10.2 ppg brine.Blow down lines.Rig up power tongs and floor safety valve. 10/24/2017 10/24/2017 0.50 COMPZN WELCTL PULL P Pull tubing hanger to rig floor.Cut 4,245.0 4,209.0 12:00 12:30 ESP cable. Lay down hanger and stab safety valve. 10/24/2017 10/24/2017 2.50 COMPZN WELCTL SLKL P PJSM-Rig up slickline and lubricator. 4,209.0 4,209.0 12:30 15:00 10/24/2017 10/24/2017 1.00 COMPZN WELCTL SLKL P RIH and set DV in GLM at 2362'WLM. 4,209.0 4,209.0 15:00 16:00 POOH with slickline. 10/24/2017 10/24/2017 0.50 COMPZN WELCTL SLKL P Rig down slickline and lubricator. 4,209.0 4,209.0 16:00 16:30 10/24/2017 10/24/2017 1.00 COMPZN RPCOMP KLWL P Rig up to circulate.Sim-ops/Talke fluid 4,209.0 4,209.0 16:30 17:30 level shot w/DHD.Fluid level in IA at —30'. 10/24/2017 10/24/2017 2.25 COMPZN RPCOMP KLWL P Reverse circulate 190 bbls 10.2 ppg 4,209.0 4,208.0 17:30 19:45 brine 1 bpm 100 psi. After 13 bbls pumped got returns.Increase rate to 2 bpm,200 psi and annulus packed off. Pick up 1'and establish reverse circulation at 1 bpm, 100 psi.Lost 29 bbls while reverse circulating. 10/24/2017 10/24/2017 0.50 COMPZN RPCOMP KLWL P Monitor well.Static loss rate 5.5 bph. 4,208.0 4,208.0 19:45 20:15 Rig down circ lines. 10/24/2017 10/25/2017 3.75 COMPZN RPCOMP PULL P POOH laying down 3 1/2" 9.3#8rd 4,208.0 2,219.0 20:15 00:00 EUE-Mod ESP completion. Removing Cannon clamps and spooling ESP cable from 4208'MD to 2219'MD.Fill hole w/3 bbls 10.2 ppg brine every 30 mins. 10/25/2017 10/25/2017 4.50 COMPZN RPCOMP PULL P POOH laying down 3 1/2" 9.3#8rd 2,219.0 96.0 00:00 04:30 EUE-Mod ESP completion.Removing Cannon clamps and spooling ESP cable from 2219'MD to Motor Hi Pot. Fill hole w/3 bbls 10.2 ppg brine every 30 mins. 10/25/2017 10/25/2017 2.50 COMPZN RPCOMP ALFT P Pull and inspect TTC ESP PCP 96.0 0.0 04:30 07:00 equipment. Found shaft in Upper Seal Section had parted in spline area. (Pictures are in the well folder S:\ANC\Longterm\Drilling&Wells Ops\G K A\1 D pad\1 D-124 RWO 2017 \Pictures\Broken Shaft of the upper Seal Section)continue to inspect remaining equipment-all inspected good. recovered-81 Cannon Clamps and 4 Protectrolizer clamps. 10/25/2017 10/25/2017 3.50 COMPZN RPCOMP BHAH P Clean and clear the rig floor of misc. 0.0 0.0 07:00 10:30 pulled de completion equipment. Offload Pulled ESP cable from spooling unit and Reload with New 7,500-ft Reel. 10/25/2017 10/25/2017 1.00 COMPZN RPCOMP SLPC P Slip and cut 52-ft of 1.25"Drill line. 0.0 0.0 10:30 11:30 Page 5/7 Report Printed: 10/31/2017 • • • Operations Summary (with Timelog Depths)• 405, 1D-124 ConocoPhillips Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB)' End Depth(ftKB) 10/25/2017 10/25/2017 4.50 COMPZN RPCOMP ALFT P Gather and RU completion equipment 0.0 0.0 11:30 16:00 for new completion spool. Pull cable over sheave. PU and MU TTC ESP PCP components. Service ESP components with oil. PU,MU to 109-ft 10/25/2017 10/25/2017 1.00 COMPZN RPCOMP OTHR P Fluid management-Pump 18.5 bbls 0.0 0.0 16:00 17:00 of Crude mixed brine to kill tank.Blow down and freeze protect lines. 10/25/2017 10/25/2017 2.00 COMPZN RPCOMP ALFT P Install.25"TEC wire from motor 0.0 109.0 17:00 19:00 gauge and High Pot to Motor. Installing 10 Motor Lead Section Cannon clamps to ESP components. Test TEC wire fittings to 5000 psi. Terminate TEC wire at DGU. 10/25/2017 10/26/2017 5.00 COMPZN RPCOMP PUTB P Pick up and RIH with 3 1/2"9.3#L-80 109.0 1,796.0 19:00 00:00 EUE 8rd Mod tubing from 109'MD to 1796'MD.Installing single channel cross collar Grippy clamps every other joint up to joint#44 and then on every joint.Pump 3 bbls 10.2 ppg brine into well every 1/2 hr. 10/26/2017 10/26/2017 0.50 COMPZN RPCOMP MPSP P Rig up and test WRP to 4000 psi/5 1,796.0 1,796.0 00:00 00:30 min. 10/26/2017 10/26/2017 0.25 COMPZN RPCOMP PULL P POOH laying down joints#54 and#53 1,796.0 1,735.0 00:30 00:45 from 1796'MD to 1735'MD. 10/26/2017 10/26/2017 0.25 COMPZN RPCOMP PUTB P Pick up packer and joint#53. 1,735.0 1,763.0 00:45 01:00 10/26/2017 10/26/2017 4.00 COMPZN RPCOMP ALFT P Perform through packer ESP cable 1,763.0 1,763.0 01:00 05:00 splice. 10/26/2017 10/26/2017 1.00 COMPZN RPCOMP ALFT T Wait for Centrilift to gather another 1,763.0 1,763.0 05:00 06:00 feed thru kit from the KCS warehouse -The Kit that was issued from Centrilift was missing the following Item"Power Sub"for connecting ESP Cable to Packer Penetrator 10/26/2017 10/26/2017 0.50 COMPZN RPCOMP DHEQ P Conduct after splice-cable Meg test- 1,763.0 1,794.0 06:00 06:30 Good Test. 10/26/2017 10/26/2017 4.50 COMPZN RPCOMP PUTB P Continue to RIH,Picking up 3-1/2 1,794.0 4,023.0 06:30 11:00 EUE 8rd Tubing completion as per run order-Installing single channel X- Cplg cannon clamps on every jt from 1794-ft to 4023-ft. 10/26/2017 10/26/2017 1.00 COMPZN RPCOMP RGRP T Change out power tongs due to being 4,023.0 4,023.0 11:00 12:00 unable to shift into high gear. 10/26/2017 10/26/2017 0.50 COMPZN RPCOMP PUTB P Continue to RIH,Picking up 3-1/2 4,023.0 4,213.0 12:00 12:30 EUE 8rd Tubing completion as per run order-Installing single channel X- Cplg cannon clamps on every jt from 4023-ft to 4213-ft. PU=70K SO=63K 10/26/2017 10/26/2017 0.50 COMPZN RPCOMP THGR P Make up tubing hanger and landing 4,213.0 4,223.0 12:30 13:00 joint 10/26/2017 10/26/2017 2.00 COMPZN RPCOMP ALFT P Perform ESP cable hanger splice. 4,223.0 4,223.0 13:00 15:00 Terminate at hanger and test cable and penetrator. Sim-ops/Blow down choke,kill and hole fill lines.Clean and clear rig floor.Offload brine from pits. Page 6/7 Report Printed: 10/31/2017 • • ° Operations Summary (with Timelog Depths) 1D-124 Conoco hithps Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation MKS) End Depth(ftK8)' 10/26/2017 10/26/2017 1.50 COMPZN RPCOMP THGR P Land tubing hanger.RILDS.PU=70K 4,223.0 4,255.0 15:00 16:30 SO=63K. 10/26/2017 10/26/2017 0.50 COMPZN RPCOMP THGR P Test hanger seals.250/5000 psi-10 4,255.0 0.0 16:30 17:00 mins each.Witnessed by Co Man. Sim-ops/Lay down landing joint. 10/26/2017 10/26/2017 0.50 COMPZN WHDBOP MPSP P Pull isolation sleeve.Set HP BPV and 0.0 0.0 17:00 17:30 test dart. 10/26/2017 10/26/2017 0.50 COMPZN WHDBOP WWWH P Make up stack washer.Flush BOPE. 0.0 0.0 17:30 18:00 Lay down stack washer. 10/26/2017 10/26/2017 3.50 COMPZN WHDBOP NUND P Nipple down BOPE.Sim-ops/Rig 0.0 0.0 18:00 21:30 down ESP cable sheave. 10/26/2017 10/26/2017 1.50 COMPZN WHDBOP NUND P Nipple up tree.Test hanger void.0 0.0 0.0 21:30 23:00 ring on dummy penetrator leaking. Unable to test void.Sim-ops/Change lower pipe rams to 2 3/8"solid body rams. Perform BWM on BOPE. 10/26/2017 10/27/2017 1.00 COMPZN WHDBOP NUND T Nipple down tree.Sim-ops/Perform 0.0 0.0 23:00 00:00 BWM on BOPE. 10/27/2017 10/27/2017 2.00 COMPZN WHDBOP NUND T Clean up burr on dummy penetrator 0.0 0.0 00:00 02:00 adapter flange port and change out 0 ring on dummy penetrator.NU tree and test hanger void to 5000 psi 10/27/2017 10/27/2017 1.00 COMPZN WHDBOP PRTS P Rig up to test tree.Fill tree w/diesel 0.0 0.0 02:00 03:00 and purge air.Test tree to 250/5000 psi for 5 mins each. 10/27/2017 10/27/2017 6.25 COMPZN WHDBOP FRZP P Rig up to pump freeze protect. Blow 0.0 0.0 03:00 09:15 down hard line to kill tank. PT lines at 4,000 psi. Bull head 86 bbls down the IA with diesel w/1%by volume CRW- 132 at 2 bpm at 1,000 FCP. Fill TBG with 22 bbls of Diesel-Pressure up to 4,000 psi and set Weatherford Hydro II Packer at 2,507-ft MD/2236-ft TVD. AT 1,700 psi the packer began setting, Pressure dropped to 3,450 psi in 40 minutes. PT IA at 2,000 psi for 30 minutes-Good Test. RU LRS back to TBG and Pressure test to 3,500 psi for 30 minutes-Good Test. RD LRS. 10/27/2017 10/27/2017 0.75 COMPZN RPCOMP RURD P Blow down Kill Tank lines and 0.0 0.0 09:15 10:00 Disconnect in cellar and valve box. 10/27/2017 10/27/2017 0.25 COMPZN WHDBOP MPSP P Dry rod in BPV with Vetco Gray 0.0 0.0 10:00 10:15 Service Tech Scott Vaala 10/27/2017 10/27/2017 0.75 DEMOB MOVE RURD P Close Swab and Master Valves, 0.0 0.0 10:15 11:00 Secure well and dress tree. Clean and clear cellar area. Release Doyon 14 at 11:00 hrs on 10- 27-17 Page 7/7 Report Printed: 10/31/2017 • i • 10-124 ConocoPhillips 121' MD, 16" 62.5#, H-40 3-1/2" 9.3# L-80 EUE 8rd f— 3-1/2" x 1" Camco KBMG GLM @ 2444' MD DV installed -I-4 3-1/2" x 7-%" WFT Hydrow II Packer @ 2507' MD ti 3-1/2" x 1" Camco KBMG GLM @ 2562' MD DV installed WeIlLift DGU @ 4153' MD Centrilift TTC Receiver @ 4220' MD Centrilift Tandem ESP Seal Sections @ 4224' MD Centrilift Gear Reduction unit @ 4238' MD Centrilift ESP Motor @ 4246' MD WeIlLift MGU @ 4253' MD Centrilift ESP Motor Centralizer @ 4255' MD 4,356'–4,388' MD,West Sak D- �€ Sand Perforations 4,420'–4,484' MD, West Sak A4- 1 Sand Perforations 4,514'–4,560' MD,West Sak A3- Sand Perforations 4,590'–4,672' MD,West Sak A2- Sand Perforations 5,033' MD, 7-%" 29.7#, L-80 Date: October 31,2017 Drawn By: Ron Phillips h KUP PROD • 1D-1 24 ConocoPhillips t Well Attributes Max Angle&MD TD A,i't'o i;p1i, Wellbore APIIUWI Field Name Wellbore Status ndi(") MD(ftKB) Act atm(ftKB) Corxo1}aelps 500292283300 WEST SAK PROD 51.27 3,188.65 5,047.0 -.- Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1[1.124,11/20/2017 3:37:17 PM SSSV:NONE 0 12/29/2015 Last WO: 10/27/2017 1/7/1998 Vertwal Schematic(4010411 AnnWation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: 4.905.0 2/12/1998 Rev Reason'WORKOVER(Pull and replace the pproven 11/20/2017 existing 3-1/2"ESP completion) HANGER:33.4- l Rl __ Casing Strings Casing Description OD(In) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 41.0 121.0 121.0 62.58 H-40 WELDED Casing OesenptIon OD(In) ID(in) Top(ftKB) Set Depth(SOB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread Ii i ::. l i PRODUCTION 7518 6.875 40.7 5,033.2 4,249.7 29.70 L-80 ABM-BTC Tubing Strings Tubing Descriptio String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)1...Wt(Ib/ft) Grade Top Connection TUBING-LSP PUMP 3 1/2 2.992 33.4 4,256.4 3,520.2 9.30 L-80 EUE '�'''CONDUCTO4:41.0-1210 ' "^"� Compledan Details Nominal ID Top(ftKB) Top(TVD)(SKS) Top inei(") Item Des Com (In) 33.4 33.4 0.00 HANGER Vetco Gray 10.75"x312 EUE 8rd 2.950 I' f 2,507.2 2,236.3 49.82 PACKER ESP Feed-Thru Packer.Weatherford Hydrow II Dual- 3.250 string packer 4,153.0 3,424.0 21.70 Gauge.Pump WeIIL ft Discharge Gauge Unit(S/N:14155752) 2.992 Sensor 4,219.7 3,48.6.0 21.50 ESP Intake TTC Receiving XO Coupling w/perforated intake 2.992 (S/N:13253843) 4,224.3 3,490.3 21.48 Seal Seal Section(S/N's:14107805) GAS LIFT 2.444.1 I e 4,238.1 3,503.1 21.44 Gear Box Gear Reduction Unit(SIN:14105630) 4.246.0 3.510.4 21.42 ESP Motors& ESP Motor.76 hp KMH 1360V/34A(S/N:105100380) Cables 4.252.7 3.516.7' 21.40 Gauge,Pump We)ILift Motor Gauge Unit(S/N:14126507 I. Sensor 4.254.6 3.518.4 21.39 Centralizer Motor Centralizer PACKER;2.507.1 :.n,- 4.256.4 3.520-2 21 39 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl Top(ftKB) (ftKB) (") Des Com Run Date ID(In) 4.177.0 3,446.3 21.63 SLIPSTOP 3"SLIP STOP on PACK OFF 11/1/2017 4,178.0 3,447.2 21.62 PACKOFF 312D&D PACKOFF(OAL 92') 10/31/2017 GAS UFT;2.824 4,186.0 3,454.7 21.60 PUMP 312PCPESP PUMP(OAL 33'8") 10/31/2017 Perforations&Slots Shot Dens Top(TVD) Btm(TVD) (0901516 Top(ftKB) Btm(ftKB) (ft08) (ftKB) Zone Date f) Type Com • 4,356.0 4,388.0 3,613.0 3,642.9 WS D,ID-124 2/5/1998 12.0 IPERF TCP Ultrapak:SWS 4.5" HSD 4,420.0 4,484.0 3,672.8 3,732.7 WSB.A-4,1D 2/5/1998 12.0 IPERF TCP Ultrapak:SWS 4.5" -124 HSD 4,514.0 4.560.0 3,760.8 3,804.0 WS A3,ID- 2/5/1998 12.0 (PERF TCP Ultrapak:SWS 4.5" 124 HSD SLIPSTOP,4,177.0 , 4.590.0 4,672.0 3,832.2 3,909.2 WS A2,1D- 2/5/1998 12.0 IPERE TCP Ultrapak:SWS 4.5" 124 HSD PACKOFF:4,178.0 Mandrel Inserts I. stf _ on Top(TVD) Valve Latch Port Size TRO Run i'l N Top(ftKB) (ftKB) Make Model OD(In) Sere Type Type (In) (pal) Run Date Com PUMP;4,186.0 �( 1 2.444.1 2,195.6 Camco KRMG - 1 ESP DMY BK 0.000 0.0 10/262017 ESP Intake;4,218.7 2 2,562.4 2,271.9 Cameo KRMG 1 ESP SOV BK 0.000 0.0 11/12017 20004 SW Notes:General&Safety Seal;4,224.3 End Date Annotation 8/19/2010 NOTE:View Schematic w/Alaska SchemaSc9.0 Gear Box,4,238.1 3/19/2012 NOTE:WO ESP Motors S Cables:4246.0 ,. 1027/2017 NOTE:WO(Pull and replace the existing 3-1/2"ESP completion) 'Neer Gauge,Pump Sensor',4,252.7 7 8111/1/8Centralizer:4,254.8 { I l'. IPERF,4,356.0-4,386.0- I (PERF:4.420.0-4.484.0- (PERF;4,514.0-4,560.0- (PERF:4,580.0-4.672.0 I PRODUCTION;40.7-5,033.2 111, • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg l, 1°1c1 DATE: 11/5/17 P. I. Supervisor 1'1 FROM: Matt Herrera SUBJECT: Defeated SVS Petroleum Inspector KRU 1D-124 PTD 1972170 On Nov. 5, 2017 I traveled to Kuparuk for SVS testing and met up with well testers Brian Martin and Danny Rotondo. Well KRU 1D-124 is an ESP completion and had been brought online 11/2/17. The low pressure pilot setpoint is 70 psi with a flowing tubing pressure of 166 psi. They started to bleed off the pressure to test the low pressure pilot, and at a reading of 50 psi the tester paused to ensure correct valve alignment and connection onto correct pilot switch. It was then discovered the low pressure pilot for the tubing/flowline was tie wrapped in the "CLOSED" position disabling the pilot and SSV from operation. The valve was then opened, and all other valve alignment verified for correct operation. The retest went without any failures once the low pressure pilot was put in service and the well was left online. CPAI noted they would conduct their own investigation of cause and mitigation of another like incident. Attachments: None Non-Confidential SCANNED FEB 0 5 203 2017-1105 SVS KRU 1D-124 defeated_mh.docx Page 1 of 1 XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning Project. They are available in the original file and viewable by direct inspection. File Number of Well History File PAGES TO DELETE RESCAN Complete [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original'- Pages: Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type 'OVERSIZED [] Logs of various kinds Other COMMENTS: Scanned by: ~ever~y Mildred Daretha II Date:,.~/ / /si D TO RE-SCAN Notes: Re-Scanned by: ~verb, Mildred Daretha Nathan Lowell Date: Is~ STATE OF ALASKA . ALP OIL AND GAS CONSERVATION COM•ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair w ell r Plug Perforations r Perforate r Other r Alter Casing r Rill Tubing r Stimulate - Frac r Waiver E Time Extension J Change Approved Program r Operat. Shutdow n r Stimulate - Other '"" Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development T Exploratory r 197 -217 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic (` Service r 50 029 - 22833 - 00-- DO 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25650 - — 1D 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): none Kuparuk River Field / West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 5047 feet Plugs (measured) 2658 true vertical 4263 feet Junk (measured) None Effective Depth measured 4905 feet Packer (measured) 2514 true vertical 4128 feet (true vertucal) 2241 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 121 121 PRODUCTION 4993 7.625 5033 4250 110E APR 2 4 ZU1Z R ECE`VE'D Perforation depth: Measured depth: 4356'- 4388', 4420'- 4484', 4514'- 4560', 4590' -4672' PR 1 6 201 True Vertical Depth: 3613'- 3643', 3673'- 3733', 3761'- 3804', 3832' -3909' AOG Tubing (size, grade, MD, and TVD) 3.5, L -80, 4247 MD, 3512 TVD Packers & SSSV (type, MD, and TVD) PACKER - ESP FEED - THRU PACKER, WEATHERFORD HYDROW II DUAL - STRING PACKER @ 2514 MD and 2241 TVD NO SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation shut - Subsequent to operation shut - 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory r Development f - Service r Stratigraphic r 16. Well Status after work: - Oil hi Gas r WDSPL r Daily Report of Well Operations XXXX GSTOR r WIND r WAG r GINJ E SUSP r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact Ian Toomey (7a. 263 - 4773 Printed Name Ian Toomey Title Wells Engineer Signature Phone: 263-4773 Date ` 76,- /)- S APR 161012Q, " Form 10 -404 Revised 11/2011 � 1(-/e----12-- Submit Original Only • • V , , s KUP 1D-124 CQnocQPhjllj p S 0 ? Well Attributes Max Angle & MD TD W ellbore API /UWI Fi Name Well Status Inc! MD (ftKB) Act Btm ftKB Alaska, Inc (1 1 ) (ftKB) Conoco mi 500292283300 WEST SAK PROD 51.27 3,188.65 5,047.0 P "" Comment H2S (ppm) Date Annotation End Date KB -Grd (ft) Rig Release Date SSSV: NONE Last WO: 3/19/2012 1/7/1998 Well Config: - 1D 4/13/2012 3:23:27 PM Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: 4,905.0 2/12/1998 Rev Reason: WELL REVIEW osborl 4/13/2012 Casing Strings HANGER, 33 , . - ' Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd ° CONDUCTOR 16 15.062 41.0 121.0 121.0 62.58 H -40 WELDED Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd r - PRODUCTION 7 5/8 6.875 40.7 5,033.2 4,249.7 29.70 L -80 ABM -BTC Tubing Strings I ^,I Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING 31/2 2.992 33.4 4,247.0 3,511.5 9.30 L -80 EUE8RDMOD Completion Details iiT Top Depth (TIM) Top Inc! Nomi... Top ( (ftKB) (1 Item Description Comment ID (!n) at 33.4 33.4 -0.49 HANGER VETCO GRAY TUBING HANGER 3.500 CONDUCTOR, 1121 2,513.8 2,240.5 49.83 PACKER ESP FEED -THRU PACKER, WEATHERFORD HYDROW II 2.908 DUAL- STRING PACKER 4,149.9 3,421.1 21.71 GAUGE WELLLIFT DISCHARGE GAUGE UNIT 2.992 4,209.2 3,476.3 21.53 INTAKE TTC RECEIVING XO COUPLING w/ PERFORATED INTAKE (S /N:CSE8442XA) ! 4,219.3 3,485.7 21.50 SEAL TANDEM SEAL SECTION (S /N's: C309161 / C309160 ) 4,233.1 3,498.5 21.46 GEARBOX GEAR REDUCTION UNIT (S /N: C611084) Ali 4,234.9 3,500.2 21.45 MOTOR ESP MOTOR, 76 hp KMH 1360V / 34A (S /N: 0320643) 4,243.2 3,507.9 21.43 GAUGE WELLLIFT MOTOR GAUGE UNIT (S /N: PWLE9001) MANDREL 4,245.1 3,509.7 21.42 Centralizer MOTOR CENTRALIZER (P /N: C63569) 4.500 2,391 Other In Hole (Wireline retrievable plugs, valves pumps, fish, etc.) Top Depth 111 (TVD) Top Inc! T op (ftKB) (ftKB) (1 Description Comment Run Date ID (in) 2,658.0 2,329.2 48.59 PLUG WRP SET w/WORKOVER 3/20/2012 0.000 Perforations & Slots 1 PACKER, 2,514 Shot Top (ND) Btm (TVD) Dens Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date (sh... Type Comment 4,356.0 4,388.0 3,612.8 3,642.8 WS D, 1D -124 2/5/1998 12.0 IPERF TCP Ultrapak; SWS 4.5" HSD 4,420.0 4,484.0 3,672.7 3,732.7 WSB, A -4, 2/5/1998 12.0 IPERF TCP Ultrapak; SWS 4.5" HSD 1D -124 r - ESP 4,514.0 4,560.0 3,760.8 3,804.3 WS A3, 1D-124 2/5/1998 12.0 IPERF TCP Ultrapak; SWS 4.5" HSD MANDREL, 2,627 • 4,590.0 4,672.0 3,832.4 3,909.2 WS A2, 1D-124 2/5/1998 12.0 IPERF TCP Ultrapak; SWS 4.5" HSD r Notes: General & Safety End Date Annotation 8/19/2010 NOTE: View Schematic w/ Alaska Schematic9.0 PLUG, 2,658 GAUGE, 4,150 ir II at INTAKE, 4,209 SEAL, 4,219 17.:. GEARBOX, at 4,233 MOTOR, 4,235 4 RIM tommi GAUGE, AIMS" Centralizer, 4,245 IPERF, 4,356 -4,388 - =' IPERF, 4.420 -4,484 - -- • Mandrel Details Top Depth Top Port IPERF, (ND) Inc! OD Valve Latch Size TRO Run 4,514 - 4,560 Stn Top (ftKB) (ftKB) (1 Make Model (in) Sery Type Type Tin) (psi) Run Date Com... 1 2,391.0 2,161.3 49.72 CAMCO KBMG 1 ESP DMY BK -5 0.000 0.0 3/19/2012 IPERF, � _ _ 2 2,626.8 2,308.0 48.43 CAMCO KBMG 1 ESP DMY BK -5 0.000 0.0 3/19/2012 • 4,590 -4,672 PRODUCTION, 41 -5,033 • • TD, 5,047 • • Conoc ©Phillips Time Log & Summary Wellwew Web Reporting Report Well Name: 1D Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 3/12/2012 9:00:00 AM Rig Release: 3/20/2012 6:00:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 33/11/2012 24 hr Summary Wait on Weather. Begin moving Nordic Rig 3 to 1 D -Pad. 06:00 21:00 15.00 0 0 MIRU MOVE MOB P Warm up rig move system. Waiting on access road snow removal. Wait on Power Company to de- energize power line at Pad entrance. Drove route, snow removal equipment is not able to keep up with drifting snow - suspend rig move operations - waiting on weather! 1C -Pad Access Road now open 21:00 00:00 3.00 0 0 MIRU MOVE MOB P PJSM. Begin moving Nordic Rig 3 from 1C -Pad to 1D -Pad. 03/11/2012 03/12/2012 Continue to Mob Rig to 1D-Pad. Spot Rig at 1D-124 Well Slot. Rig up. Pull BPV. Kill Well. 00:00 02:00 2.00 0 0 MIRU MOVE MOB P Continue moving Nordic Rig 3 from KIC area to 1 D -Pad. 02:00 08:00 6.00 0 0 MIRU MOVE RURD P Rig arrived on 1D-Pad. Move over 1D-124 Well (Drill Site Operator present). Shim and level up Rig. 08:00 12:00 4.00 0 0 MIRU MOVE RURD P Berm up and secure Cellar. Spot Rig support equipment. Take on Filtered 8.6 lb/gal w /3% KCL fluid in Pits. 12:00 13:00 1.00 0 0 MIRU MOVE RURD P Spot and berm up Kill Tank. 13:00 16:30 3.50 0 0 MIRU WHDBO MPSP P PJSM. Pick -up Lubricator. Attempted to pull BPV. However, unable to open the Swab Valve (pressure locked). Call out Valve Crew to service Swab and Master Valves. Open Swab Valve and pull BPV. Lay down BPV and Lubricator. 16:30 18:00 1.50 0 0 COMPZ WELCTI KLWL P Rig up Hoses and hard line to Kill Tank. Test line with air. Good. Page 1 of 8 • . Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 00:00 6.00 0 0 COMPZ WELCTI KLWL P PJSM. Reverse Circulate,Well with 129 F filtered_ 8.6,11o/gal w /3 % KCB, fluid at 3.0 bpm /170 psi. Good returns. Increase rate to 5.0 bpm /390 psi. Total volume pumped = 286 bbls. Bullhead 25 bbls at 2.0 bpm /635 psi to clear the Casing below the ESP Pump. Monitor Well. Well continues to flow back at 10 psi. Reverse in a second hole volume. Monitor Well. Well finally died. Now on a slight vacuum. 03/13/2012 Install and test BPV. Nipple down Tree. Nipple up 11" 5K BOP Stack. Perform the initial BOPE Test. 00:00 01:00 1.00 0 0 COMPZ WELCTI MPSP P jnsfall BPV Test from below. Good. 01:00 03:00 2.00 0 0 COMPZ WHDBO NUND P Nipple down Production Tree. 03:00 10:00 7.00 0 0 COMPZ WHDBO NUND P Nipple up 11" x 5k BOP Stack (3 1/2" Solid Ram Blocks in top gate, 2 7/8" x 5" VBR Blocks in bottom gate). 10:00 16:30 6.50 0 0 COMPZ WHDBO PRTS P PJSM. Begin the initial BOPE test per ConocoPhillips, AOGCC requirements at 250/3,000 psi. The .f;°fy State's right to witness the test was waived by AOGCC Field Inspector, M. Herrera. However, unable to begin the official test due to chasing a pressure fall- off /leak. 16:30 18:30 2.00 0 0 COMPZ WHDBO PRTS T Discovered a small seep coming / from an Upper Pipe Door Seal. V Replace Door Seal. 18:30 00:00 5.50 0 0 COMPZ WHDBO PRTS P Resume BOPE testing. Found a second Door Seal Leak. This one was on the Blind Ram Door. Replace Door Seal Gasket. Resume testing. However, still chasing slight pressure fall -off "mystery leak" No further visible surface leaks. Call out Wellhead Service Rep. 03/14/2012 Perform the initial BOPE test. Rig up to pull the 2 7/8" ESP Completion. Pull Tubing Hanger to Floor. Circulate and condition the hole. Begin to single down the 2 7/8" ESP Completion. 00:00 01:30 1.50 0 0 COMPZ WHDBO MPSP T Vetco -Gray Service Rep trouble shoot Tubing Hanger /BPV /Blanking Plug. Nothing obvious was found. (However, the possibility that the ESP or the Heat Trace Penetrator could be leaking by ?). Page 2 of 8 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:30 04:30 3.00 0 0 COMPZ WHDBO PRTS P Finally got a good solid stright line high pressure test on the chart. It is now assumed that one of the Penetrator was in fact seeping by and the repeated pressure attempts sealed off the leak. Begin the official Initial BOPE test at 250/3,000 psi. per ConocoPhillips, AOGCC requirements. Looking good. Perform Koomey Draw Down Test. Good. All pressure test were recorded on a chart. 04:30 05:00 0.50 0 0 COMPZ WHDBO MPSP P Vetco -Gray Service Rep pulled the Blanking Plug and the Back Pressure Valve. 05:00 06:00 1.00 0 0 COMPZ RPCOM THGR P Landina,fgint__BOLDS 06:00 07:30 1.50 0 0 COMPZ RPCOM PULL P PJSM. Pull Hanger. Breakover _ at 115k. free weight 70k uo and 65k down. 07:30 09:30 2.00 0 0 COMPZ RPCOM CIRC P Line up Mud pump to circulate down tubing. Pump 290 bbls of 8.6 ppg KCL, with 3% kcl to clean tubing at 5 bpm, 520 ICP, 520 FCP, circulate until return are clean. 09:30 11:00 1.50 0 0 COMPZ RPCOM OWFF P Blow down top drive. Monitor well for flow. PJSM with all party involved in pulling ESP completion. C/O handling Equipment. 11:00 12:00 1.00 0 0 COMPZ RPCOM CIRC P Sill seeing large amount of Gas in returns. Line up rig pump and circulate until gas is not present in returns. Pump rate 5 bpm, at 570 psi. (170 bbls). 12:00 00:00 12.00 4,254 0 COMPZ RPCOM PULL P Monitor well for 15 minutes. No Gas Present. P ull Hanger to RigFloor and lay down same. Single down the 2 7/8" ESP /HT Completion from 4,254 -ft Up Weight = 70K. Down Weight = 65K. (loaded Pipe Shed with 3 1/2" Drill Pipe and 2 7/8" Hydril 511 Tubing). 03/15/2012 Inspect and lay down ESP Assembly. Pick -up Clean -out BHA. Single in on 3 1/2" Drill Pipe. Clean out Gravel Pack Screens. Trip out. Lay down the 2 7/8 Tbg. Stand -back the Drill Pipe. 00:00 03:00 3.00 0 0 COMPZ RPCOM PULD P Inspect and lay down ESP Assembly Motor checked ok. Pumps turned stiff, Seal Assembly, dry. Cable checked good. Some scale was noticed on the Motor and Seal Assembly. The Lower Cable Connector just below the Tubing Hanger checked bad. No bands of Flat guards were lost in the hole. 03:00 04:00 1.00 0 0 COMPZ RPCOM OTHR P Clear and clean Rig Floor. 04:00 06:00 2.00 0 655 COMPZ RPCOM PUTB P PJSM. Install Wear Bushing. Make -up 2 7/8" Mule shoe. Single in with 2 7/8" Hydril 511 Tubing. Page 3 of 8 • • Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 06:00 07:00 1.00 655 683 COMPZ RPCOM PULD P MU 7 5/8" Casing Scraper Assembly. 07:00 10:30 3.50 683 4,100 COMPZ RPCOM TRIP P Continue to TIH with C/O and Scraper Assembly on Drill Pipe. 10:30 12:00 1.50 4,100 4,100 COMPZ RPCOM OTHR P Stop and Make 2nd Band and Clamp count recovered from well and unload clamps down beaver slide. 12:00 14:45 2.75 4,100 4,887 COMPZ RPCOM TRIP P Continue in hole with C/O assembly_ Tagged Top of Fill at 4 887 ft 14:45 16:00 1.25 4,887 4,892 COMPZ RPCOM CIRC P Line Up Mud Pump and Reverse Circulate fill down to 4,892 -ft-ft. Pump rate 4 bpm at 480 psi. Saw a small trace of fill at the shakers with 30% loses during pumping operation. Attempted to CBU x1 to confirmed wellbore is clean. However, the Drill Pipe "plugged -off'. Up Weight = 95K. Down Weight = 81 K. 16:00 17:00 1.00 4,892 4,163 COMPZ RPCOM TRIP P Pull back up above the SC -1 Packer and park inside the 7 5/8" Casing. Attempt to "un- plug" Clean -out String. No -Joy. 17:00 17:00 0.00 4,163 682 COMPZ RPCOM TRIP P PJSM. Trip out standing back the 3 1/2" Drill Pipe in the Derrick to the Casing Scraper. 17:00 20:00 3.00 682 0 COMPZ RPCOM PUTB P Lay down the 7 5/8" Casing Scraper, Bumper Sub, and Oil Jar. Change out handling equipment. Single down the 2 7/8" Hydril 511 Tubing in the Pipe Shed. Clear and clean Floor. 20:00 00:00 4.00 0 4,250 COMPZ RPCOM TRIP P PJSM. Pickup Baker Retrievable__ Bridge and Test Packer. Trip in with 3 1/2" Drill Pipe from the derrick to 4,250 -ft. Up Weight = 90K. Down Weight = 77K. 03/16/2012 RIH w/ Baker Retrievable Bridge Plug and Test Packer. Set RBP. Test the 7 5/8" Casing. Good. Release RBP. Trip out. Lay down RBP and Packer Trip in w/ 3 1/2" DP Kill String. Temporary suspend operations due to field wide cold weather shut -down. 00:00 01:00 1.00 4,250 4,250 COMPZ RPCOM PRTS P Set the Retrievable Bridge Plug. Pressure test the 7 5/8" Casing at 1 30 min4tgs.. "Rock solid test ". Record test on a chart. (Note: Did not set the Packer since it was not needed for a "leak- hunt "). 01:00 03:00 2.00 4,250 0 COMPZ RPCOM TRIP P Release the Retrievable Plug. Trip out standing the 3 1/2" Drill Pipe in the Derrick. Lay down the Retrievable Bridge Plug, Running Tool, and the Packer. Page 4 of 8 4. • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:00 03:30 0.50 0 2 COMPZ RPCOM TRIP T Trip back in with a 3 1/2" Drill Pipe Kill String to 2,125 -ft. Unable to load Pipe Shed with Completion Equipment and Tubing due to cold weather shut down restrictions (-47 Below). Monitor Well. Will resume operations when the restrictions are lifted (at -35 below). 03:30 12:00 8.50 2,125 2,125 COMPZ RPCOM OTHR T Continue Waiting on Weather. 12:00 00:00 12.00 2,125 COMPZ RPCOM OTHR T Continue Cold Weather Shut -Down. 3 1/2" Drill Pipe Kill string remains in Well. Continue to monitor Well. _ Fluid loss = 6.0 bbl /hr. 03/17/2012 Continue to Wait on Weather. Temporary suspend operations due to field wide cold weather shut -down. Resume Operations. Trip out with the 3 1/2" Kill String. Prep to run the 3 1/2" ESP Completion. 00:00 14:00 14.00 2,125 2,125 COMPZ RPCOM OTHR T Continue Cold Weather Shut -Down. 3 1/2" Drill Pipe Kill String remains in Well. Continue to monitor Well. Fluid loss = 6.0 bbl /hr. 14:00 15:30 1.50 2,125 0 COMPZ RPCOM TRIP P PJSM. Resume Operations. Trip out with the 3 1/2" Kill String from 2,125 -ft. 15:30 16:30 1.00 0 0 COMPZ RPCOM RURD P Clear and Clean Floor. Swap out Handling Equipment. 16:30 18:00 1.50 0 0 COMPZ RPCOM OTHR P PJSM. Spot Crane. Change out ESP Cable Spools. 18:00 20:00 2.00 0 0 COMPZ RPCOM RURD P Load and organize ESP Equipment Finish rigging up to run the completion. Pull Wear Bushing. 20:00 00:00 4.00 0 0 COMPZ RPCOM ALFT P PJSM. Make -up the ESP Assembly. Service same. Attach the TEC Wire. Attach the Motor Lead Extension Cable to the Motor. 03/18/2012 Rig up to run the 3 1/2" ESP Completion. Make -up and service the ESP Assembly. Single in the ESP Completion with 3 1/2" Tubing from the Pipe Shed. 00:00 01:30 1.50 0 0 COMPZ RPCOM ALFT P Continue to service the ESP Assembly. 01:30 03:00 1.50 0 1,732 COMPZ RPCOM RCST P Single in the 3 1/2" ESP Completion, as designed. Make -up the Weatherford Hydrow II Packer 03:00 07:30 4.50 1,732 1,732 COMPZ RPCOM OTHR P Splice the Cable thru the Weatherford ESP Feed -Thru Packer. Test Cable. 07:30 08:00 0.50 1,732 1,732 COMPZ RPCOM SFTY P PJSM. Discuss Hazard for running ESP Completion. 08:00 12:30 4.50 1,732 4,213 COMPZ RPCOM RCST P Continue to TIH with 3 -1/2" Completion as designed and perform electrical inspection / test on the ESP power cable every 1000 -ft. 12:30 12:45 0.25 4,213 4,213 COMPZ RPCOM RCST P MU Vetco Gray Tubing Hanger. Make final ESP cable splice to penetrator and check ESP cable / motor electrical integrity. Page 5 of 8 II • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:45 22:30 9.75 4,213 4,213 COMPZ RPCOM PULL T While performing final ESP Cable electrical integrity test, was unable to get a final test, Results was a_wgt test. PJSM for job scope change. Start TOOH with completion to find damage area on cable. Up Wt, 81k. Stopped at the Packer to check ESP feed -thru connections. Trouble shoot connections. However, found no visible problems. Re -make both the upper and lower ESP connections. Check Cable. Good. Trip back in with the 3 1/2" ESP Completion. Checked the ESP Cable several times. Check good. Make -up Tubing Hanger. 22:30 00:00 1.50 4,213 4,213 COMPZ RPCOM OTHR P Install Penetrators. Make top ESP Cable Splice. 03/19/2012 Land Tubing Hanger. Freeze protect Well. RU S -Line. Set WRP. WRP failed to set properly. No pressure test. Pull WRP. Wait on WRP #2 and Setting Tool. 00:00 02:00 2.00 4,213 4,213 COMPZ RPCOM OTHR P Complete ESP Top Splice and attach to the Tubing Hanger. Check Cable. Good. Phase to Phase = 2.0 Ohms, Phase to Ground = 3.0 G /Ohms. Pressure = 1,552 psi, Tempeture = 70 degs F. 02:00 03:00 1.00 4,213 4,247 COMPZ RPCOM THGR P Drain Stack. Land Tubing Hanger.__ RILDS. Test Pack -off at 5,000 psi x 15 minutes. Good. 03:00 08:00 5.00 4,247 4,247 COMPZ RPCOM FRZP P PJSM. Spot and rig up Lil' Red Services. Pressure test Line at 1,000 psi. Bullhead 30 bbls of Stright diesel down the Tubing at 0.7 bpm /375 psi. Shut in tubing. Hook up Lil' Red line to the 7 5/8" x 3 1/2" Annulus. Begin pumping 90,bbls of Gelled diesel down the IA at 1 bpm, ICP 150 psi, FCP 550 psi. R/D LRS and stage on edge of location, release vac truck. 08:00 11:30 3.50 4,247 4,247 COMPZ RPCOM OTHR P MIRU crane next to rig to pull thermo siphon. 11:30 12:00 0.50 4,247 4,247 COMPZ RPCOM SFTY P Hold PJSM with Slick -line, Nordic, LRS and weatherford for setting WRP and Feed Thru Packer. 12:00 12:45 0.75 4,247 4,247 COMPZ RPCOM SLKL P MIRU Slick -line and Load Equipment to Rig Floor. Page 6 of 8 • • • Time Logs Date From T. Dur S. Depth E. Depth Phase Code Subcode T Comment 12:45 19:00 6.25 4,247 4,247 COMPZ RPCOM SLKL P RU Lubricator Section and PT same to 500 psi. RIH and perform dummy drift run down to 2500 -ft. Make tie -in correlation run. RIH and set 3 -1/2" WRP at (2,650-ft) in the middle of the firs t full joint below the bottom GLM at 2626 -ft. Set WRP. However, the DPU Setting Tool did not indicate a good sign on surface that the WRP set completely. POOH with setting Tool. Setting Tool sheared normally. However, after a tear -down field inspection it appeared that the motor had burnt up. 19:00 00:00 5.00 4,247 4,247 COMPZ RPCOM PRTS T Attempted to pressure test WRP. Lil' Red pumped diesel down the Tubing at 1.0 bpm /400 psi x 5 total bbls. Shut down. Observe a rapid pressure fall -off. Make a second attempt with the same results. Re -group to pull the WRP, re -build the Setting Tool, and order out a new WRP. Unable to re -build the Halliburton Setting Tool. Order out _ Weatherfor:0 Slick Pump setting__ tool. While waiting for the Slick Pump setting tool, S -line make a drift run to simulate the Slick Pump setting Tool. Also flag line. 03/20/2012 Set WRP #2. Pressure test the WRP. RD S -Line. Set Weatherford Packer. Pressure test Casing. Set BPV. Nipple down BOP Stack. Nipple up Tree. Prep to RDMO. 00:00 02:30 2.50 4,247 4,247 COMPZ RPCOM PLUG T Continue to wait on WRP #2 and the setting Pump. (Rig move in the BP Field delayed arrival of WRP). 02:30 04:45 2.25 4,247 4,247 COMPZ RPCOM PLUG T WRP arrive on Location. Make-up Weatherford Slick Pump and WRP #2. Pressure test Lubricator to 500 psi. Good. Open Well and have Lil Red pump 5 bbls of Diesel to clear Tubing. RIH with WRP #2. Correlate to "flag ". Set WRP #2 at 2,658 -ft. Cycle the Slick Pump 35 times to shear free from the WRP. POOH. 04:45 05:15 0.50 4,247 4,247 COMPZ RPCOM PRTS P Lil Red Pressure test the WRP at 500 psi x 5 minutes Good. Rig � S -line off of Well. t 05:15 07:30 2.25 4,247 4,247 COMPZ RPCOM PACK P Re- configure top of Tubing to set the Packer and hook up the Chart Recorder. Step up pressure to 3000 psi to set Hydrow II packer and test tubing Integrity for 15 minutes. Pressure up on IA and test to 1500 psi for 30 minutes, lost 80 psi for the first 15 minutes and a total of 97 psi for 30 minutes. RDMO Slick -line. Page 7of8 • . Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:30 11:00 3.50 4,247 4,247 COMPZ RPCOM PRTS P Good Test on IA. De= pressurize the annulus per schedule. Rig Down LRS, and Testing Equipment. 11:00 11:30 0.50 0 0 COMPZ WELCTL MPSP P Back out landing joint, drain stack. Install two -way check. 11:30 11:45 0.25 0 0 COMPZ WHDBO SFTY P Hold PJSM. Discuss Hazard for ND BOPE 11:45 14:30 2.75 0 0 COMPZ WHDBO NUND P ND BOP Stack. 14:30 15:30 1.00 0 0 COMPZ WHDBO NUND P Check the ESP cable /motor electrical intergirty. NU tubing head adapter & tree. 15:30 16:00 0.50 0 0 COMPZ WHDBO PRTS P PT Tree to 5000 psi for 5 minutes. Pt Hanger void and pack -off to 5000 psi for 5 minutes. Perform final ESP cable /motor electrical intergirty. Test Good. 16:00 16:30 0.50 0 0 COMPZ WHDBO PLUG P Pull two -way check valve. Set 3" 'H' BPV. 16:30 18:00 1.50 0 0 COMPZ MOVE MOB P Clean Pits. R/D treating iron and prep for Rig Move. (Released Rig at 1800 hours.) Page 8 of 8 ~~~ ~~Q~~~~ ~~ PROACTIVE DAAGINOSTIC SERVICES INC. To: AOGCC Christine 14Aaf~rtken $!~~'~'z-~( 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road ~~~ ~~~~u . ~i,l~t:~ ~` ~ ~~~~ Suite C Anchorage, AK 99518 Fax: (907j 245-8952 1) MTT Report 24,Jun-10 50-029-22839-00 2) MTT Report 24,1an-10 1 D-1 18 1 Report 1(}124 1 Report 50-029-22 ,~~-aa~ ,~~-- Signed Print Name: ±UL 2 x.2010 Date X11 .Otx»n~issi~ A PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 Fax: (907)2458852 E-MAIL : pdsanchoragetc~memorviog.com WEBSITE : www.memora~loq.com C:\Docoments and Settings\Diane Williams\Desktop\Tiansmit_Conoco.docx Memory Magnetic Thickness 7ov1 Lag Results Summary Gompany: ConocoPhillips Alaska, Inc. Well: 1 D-124 Log Date: June 24, 2010 Field: West Sak Log No.: 7414 State: Alaska Run No.: 1 API No.: 50-029-22833-00 Pipet Desc.: 2.875" 6.5 fb L-80 EUE 8RD-MOD Top Log Intvl.: Surface Pipet Use: Tubing Bot. Log Intvl.: 225 Ft. (MD) Pipet Desc.: 7.625" 29.7 Ib L-80 Top Log Inivl.: Surface Pipet Use: Production Casing Bot. Log Intvl.: 225 Ft. (MD) Pipe3 Desc.: 16fl 62.58 Ib. H-40 Top Log Intvl.: Surface Pipe3 Use: Conductor Pipe Bot. Log Inivl.: 121 Ft. (MD) Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS This MTT data is tied into the Mandrel Hanger @ 0' Depth. This is the first time this well has been logged with the 12 Arm Magnetic Thickness Tool (MTT). The MTT responds to the total metal thickness of the 2.875" tubing, 7.625" production casing, with some influence from the 16" conductor pipe. Passes at 5Hz, 8Hz and 10Hz were made at 20 fpm. INTERPRETATION OF MTT LOG RESULTS The MTT log results cover the interval from surface to 225'. Changes in metal volume are relative to the calibration points at 32' and 150', where the readings are assumed to represent undamaged pipe. All other readings are relative to these reference points, which include influences from the 2.875" tubing, 7.625" casing and 16" conductor pipe. A log plot overlay of the average overall metal thickness recorded by the 5Hz, 8Hz and 10Hz passes is included in this report. This plot indicates metal loss features over the intervals 3' - 8', 20' - 26', 37' - 41', 44' - 47', 47' - 55', 55' - 72' and 202' - 225', with their maximum metal loss indicated in all three passes list in the table below. ...Maximum Metal Loss Depth SHz 8Hz 10Hz 20' - 26' 13°k 8% 3% 37' - 41' 2% 3% 4% 4T - 55' 1 % 3% 5% 55' - 72' 7% 11 % 12% 202' - 225' 4% 3% 3% The lower frequency passes show more metal loss response than the higher frequency passes over the intervals (20' - 26') and (44' - 47'). Since the lower frequency magnetic signals are more capable of permeating metal further from the tool than the higher frequency signals, the response from the 5Hz pass is considered to be more representative of the relative overall metal loss further away from the tool in these intervals. A log plot of the entire 5Hz pass and an expanded log plot of -top 30' of the 5Hz pass are included in this report. ?ro(actve Diagnostic Services, Tnc. .r' P.G. Box 1361}, Safford, -i-~ %%49;~ P"ore: (ZB; } or X586) 865-90755 Fax: ;'S1) `.i65-136~~~ E-~maii: PDS,~me~morylog,com Pi:dhoe Bay Field Office Phone: 90?j 659-230? Fax: (907; 6`~=1'GJ1y r9~- -al ~ The higher frequency passes show more metal loss response than the lower frequency passes over the intervals (47' - 55') and (55' - 72'). The response from the 10Hz pass in these intervals is considered to be more representative of the relative overall metal loss spatially closer to the tool. A log plot of the entire 10Hz pass is included in this report. The differences of the tool responses to metal loss over various frequencies suggests the metal toss over the intervals (47' - 55') and (55' - 72') is comparatively loser to the tool than the metal loss over the intervals (20' - 26') and (44' - 47'). The similarity of the toot response to metal loss over various frequencies over the remaining metal loss intervals suggests the metal loss may be mare evenly distributed between the inner and outer layers /surfaces of the concentric string(s). The percent circumferential metal loss expressed in this summary is a percentage of the total metal that the tool is responding to, which may include influences from the 2.875", 7.625" and 16" pipe. If all of the metal loss is specific to the 7.625° production casing, the percent metal loss from that pipe alone is probably higher than the numbers expressed. Some of the metal loss indicated could be from either the 2.875" tubing or 16" conductor. ' Field Engineer: Wm. McCrossan Analyst: HY. Yang & J. Burton Witness: J. Condio ProActive Diagnostic Services, Inc. ? P.O, Box 1369, Stafford, ?'?C 77497 Phone; (281) or (888) 565-9985 Fax: (281; 565-1369 E-mail: PDS~a;memor~~iog,com 1 Prudhoe Bay Field Office Phone: (907) 659-2347 Fax; (907} 659-231# o``""`~Eus 5Hz, 8 and 10Hz Delta Metal Thic ess Passes Overlay y ~ Ate, 1 D-124 June 24, 2010 PooAcrirc ~inynosric Scaviccs Database File: d:lwarriordatalld-12413rd overlay.db Dataset Pathname: overlay Presentation Format: overlay Dataset Creation: Fri Jun 25 17:26:37 2010 Charted by: Depth in Feet scaled 1:150 -50 Delta Metal Thickr~ss 2010 (10Hz) (%) 50 -5D Delta Metal Thickness 2010 (8Hz) (%) 50 -50 Delta Metal Thickness 2010 (5Hz) (%) 50 0 20 40 _ ~'-^8Hz Delta Metal 60 ~~--~~ 10Hz Delta Metal 5Hz Delta Metal Thickness Bottom of 16" 80 100 120 140 160 Delta Metal 180 200 220 I 110Hz Delta Metal Thickness -+- Delta Metal Thickness ~~ ~E~.t A~ R~rded Magnetic Thickness L~ Data - 5Hz Pass ' a ~~. ~ '~ 1 D-124 June 24, 2010 Pn°Amvc Oin ,hosric Scwviccs Database File: d:Iwarriorldatal1d-1241passes.db Dataset Pathname: 5HzPass 1 Presentation Format: 18 Dataset Creation: Tue Jun 29 08:46:55 2010 Charted by: Depth in Feet scaled 1:150 -50 Delta Metal Thickness {%) 50 1.8 MTTP01 {rad) 11. 0 Line Speed (ft/min) -200 -7 MTTP12 {rad) ' Tree ' Line S ~-langer~ Metal Loss Pup 2.875" Colla ~ 2.875" Collar `E Delta Metal Thickness 13% Metal Loss Tubing Jt. 1 7.625" Collar ~ 2.875" Collar ~ 7% Metal Loss Tubing Jt. 2 60 ' 7% Metal Loss 2.875" Collar ~ ' Bottom of 16" Conductor 80 ' 7.625" Collar - Tubing Jt. 3 . ,,,, o`er"wE~`s~°~,, nded 5Hz Pass Magnetic T 'ckness Log Data as M 1 D-124 June 24, 2010 P11°/~GTIV[ QIASN°StfC S[RVICCS Database File: d:lwarriorldatal1d-124\expanded 5hzpass.db Dataset Pathname: SHzPass Presentation Format: 18 Dataset Creation: Tue Jun 29 08:46:55 2010 Charted by: Depth in Feet scaled 1:60 -50 Delta Metal Thickness {%} 50 1.8 MTTP01 (rad) 11.8 0 ~ _ _ Line Speed (ft/min} -200 -7 MTTP12 {rad) 3 Tree 5% Metal Loss ~ Pup i i i i II Pup 875" Collar ~~ Delta Metal Thickness 20 13% Metal Loss Tubing Jt. 1 30 -50 Delta Metal Thickness {%) 50 1.8 0 Line Speed (ft/min) -200 -7 MTTP01 (rad) MTTP12 (rad) 11.81 It ~ i ConocoPhillips Alaska, Inc. -- Wire #, (33-z27o, oD:t.ooo) W tre #2 (33-a25a, ' OD:1.000) ' Gas Lift 3ndrei/Dummy VaWe 1 (4171-4172, OD:5.500) TUBING (o-a25a, oD:a.675, ID:2.441) PUP (4214-4215, ' OD:2.875) PUMP#1 (4222-4236, OD:4.000) PUMP:O@ (4236-4237, 00:4.OOD) SEAL (4237-4247, OD:5.130) MOTOR (4247-4254, OD:5.620) Perf (4356-4388) PeA (4420-4484) ' PeA (4514-4560) ' PROD. CASING (0.5033, OD:7.625, ' Wt29.70) Pert (4590.4672) ~KRU 1 D-124 1 D-124 API: 500292283300 Well T e: PROD An le TS: d SSSV Type: NONE Orig Com lotion: 1/7/1998 Angle ~ TD: 19 deg ~ 5047 Annular Fluid: Last W/O: Rev Reason: Set DCR Reference L Ref LogDate: Last U ate: 8/7/2005 Last Ts : 4905 _ TD : 5047 ftK6 Last Tag Date: 2/12/1998 _ Max Hole An le: 51 deg ~ 3189 Casin String -CONDUCTOR __ Description Size To Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 121 121 62.58 H-40 ' Cesin Strin -PRODUCTION Descri tion Size To Bottom TVD Wt Grade Thread PROD. CASING 7.825 0 5033 4249 29.70 L-80 _ Tubin Strin -TUBING Size To Bottom TVD Wt Grede Thread 2.875 0 4254 3518 6.50 L-80 EUE 8RD MOD Perforations Summa Interval TVD Zone Status Ft SPF Date T Comment 4356 -4388 31313 - 3643 WS D 32 12 2/5/1998 IPERF TCP Ultrapak; SWS 4.5' HSD 4420 - A484 3673 - 3733 WS B,WS A4 64 12 2/5/1998 IPERF TCP Ultrapak; SWS 4.5' HSD 4514 -4560 3781 - 3804 INS A3 46 12 2/5/1998 IPERF TCP Ultrapak; SWS 4.5" HSD 4590 -4672 3832 - 3909 WS A2 82 12 2/5/1998 IPERF TCP Ultrepak; SW3 4.5" HSD Gas Lift MandrelsNaNes St MD ND Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt 1 4171 3441 Campo KBMM DCR 1.0 BK 0.000 3000 8/4/2005 Other lu s, a ui .etc. -JEWELRY D~th i TVD T e Descri lion ID 33 33 Wire #1 Ra chem Heat Trace Bottom de th 2270' 0.000 33 _ 33 _W ire #2 ESP Electric W/I Wire Cable Bottom de th 4524 0.000 _ 4210 3477 _ GAUGE Baker Sensor Gau a 2.441 4214 3481 PUP 2 718 EUE 8RD MOD 2.441 _4222 _ _3488 PUMP #1 CenVilift ESP Pump FPMT/AR 0.000 4236 3501 PUMP #2 Centrilift ESP Pum FPMT/AR w/ intake 0.000 4237 3502 SEAL Centrilift Seal Section GSFTDBHL 0.000 4247 3511 MOTOR ESP Centrilift MOTOR KMH 1325/26 0.000 Ri=t~EIVED 06125!2010 10:ab 281431715 ?DS COt~~' Jun 2510 07:44a PDS Prudhoe ~ ' 9076314 P,1 i, TUBING ESP Electric Submersible PumA Completion 1 Q-124 (G3) ARCO Alaska, Inc. GATE: 02/io/9s Subs~d3arvnfAlianticRidf6etdGcrnaanv ~ At ~ De!`CC #Y ITEIiiIS , COMPlETE DESCRIPTION OF EQUIPMENT.RUN LENGTH OEPTH CentrHNt I TOPS Ncte: Used 2 Protectol¢ers 5 feat Able card 27 steel bands 36 LaSalle cable clamps 146 Preformed Bands Ra Chem Heat Trace -2270' Actual 13.9 +!- lon Note: Used 351 v b flat cafe uara 15 4' Ion gat cable uard i5 ;i lon flat cable rd 1 6' lan end shoe 1148 steel bangs FINAL COMPLETION RIG FLOOR TO LDS -Packer 245 33.37 A8B Vetto Gray Tu' ~ Han er W! 2 7t8" L-80 EUE Brd Mad Pup Jant 3.18 33.37 Space Out Pips as Required - 2 716' 6.5ar EUE tkd h4od(.83,.32„32,.32,10. iZ,2.131 14,01 $6.55 Jt #2-133 JT 2 718" 6.5# L-80 EUE Brd Mod Tut>in (as recuked) 4115.53 50.56 X-Over Pup - 2 lt8" S.5tt EUc Brd Mod Bcx x 2 718" 6.5# Mod Butt Pin 5.34 4166.09 2 7!8" X 1 "Camco 'KBMM GLM W/ STS -1 TBG SHEAR Valve B.48 4171,43 X-Over Pup - 2 7t8" 6.5# Mod 3utt Box x 2 7!8" 8.5# EUE 3rd Mod Pin 5.32 4177.91 Jf #1 JT 1 Joint 2 718" 6,5# L-80 EUE Brd Mod Tubin - 3aker Sensor Gauge Attached 31,05 4183.23 Handlin Pup - 2 718" 8.5# EUE Brd Mod 8.15 4214.28 ESP Pump FPMT AR 4.00" OD 13.67 4222.43 ESP Pump FPMTlAR 1N/ Ir+taiccbn 4.00'' DD .68 4236.10 ESP Seai Section GSr'T DB HL PFS - 5.130 OG 9.91 4236.58 ESP PCESP !44otor 57 HP 1315128 KMH - 5.620 OD 5.86 4246.89 4253.75 I ~ Note- Circuiatirg Vaive Installed in 2 l!8" CamW GLh1 After Ri moved Note: R Chem Heat Trace attached ~ 10' Fl thread end of joint # 61 Note: BOT Sensor Gau attached 4' F! thread end of joint # 1 Remarks- String Weights with Blocks- 42K# Up, 32K# On, 8K# Blocks. Ran 133 poi nts of tubi;~ . t?rlrted ttmmg, c~t.MS. ik Hanger, Vsed Att:tic Grade API Modified No Lead thread comoot:rtd on ail connections. Tubing is non-coated. Nordic Rig #2 Dritlfnct Supervisory ~Wark Chambers -='cI51cL~ ~~k~~t•~c,i'~~!10 it~:4i=. ~cia~l~~:~.~ ^[,,; ;~~~R-~ !un?~'007a4a PGSRrudhoa • "5076314 p.~~ ARCO At.A5KA INC ? TUBING TALLY PAGE: 1 of 2 WELL NUMBER: f 0-124 {G31 Kuparuk River Unit RtG: Nordic Rig it2 TU$tNG OESCRIPTIOtd: 2-718"", 6.5#, L-80, A8M-EUE, Non-Coated -Range 2 -Class A oArE: D~14er9a Column 1 Column 2 Column 3 Column 4 Column 5 Column 6 Gotumn T Column 8 No Feet No Feet No Feet No Feet No Feet No Feet No Feet No Feet 1 31.05 26 31.05 51 31.50 T6 31.08 101 31.07 126 31.02 151 176 2 31.04 Z7 31.03 5T 31.56 77 31.02 102 31.09 127 31,07 152 177 3 31.10 28 31.51 53 31.05 78 31.40 103 31.02 128 31.16 153 178 4 3":.05 29 31.52 54 31.56 79 31.69 104 31.06 129 31.0"0 154 179 5 31,10 30 31.55 SS 31.05 80 31.08 105 31.02 130 31.82 155 180 6 31.04 31 31.82 56 31.07 81 31.88 106 30.31 131 ~ 31,59 156 1 181 7 31.65 32 31.08 57 31.10 J 82 31.82 107 3t .08 132 31.74 ~ 157 182 8 30.05 33 30.84 58 31 .D8 83 31.09 t08 31.08 133 31.02 158 183 9 30.04 34 31.03 S9 31.05 ~ 84 31,08 109 31 A7 134 3t.G9 159 184 t0 3t.50 35 31,92 60 3.20 85 31.08 110 31 A2 135 1 31.93 t6D 185 t1 31.27 36 30.68 61 31.42 86 31.08 111 31.08 136 31.G3 161 186 12 31.51 37 31.03 62 31.02 87 31.52 112 31.03 1ST 31.78 162 187 13 31.52 38 31.06 63 31.10 88 31.53 113 31.06 138 31.08 163 188 14 31.57 39 31.43 64 31.28 89 31.08 114 31.84 139 31.80 1 189 15 31.Q4 40 31.08 65 31.03 90 3t,54 115 31.82 140 31.91 165 190 16 30.40 41 31.10 66 31.04 91 31.06 116 31.80 141 166 191 17 30.70 4Z 29.82 67 31.68 92 31.54 117 31.G6 142 167 192f i8 31.09 43 31.04 ~ 31.03 93 1 31.09 1 i 8 3t .57 143 168 193 19 31.54 44 :11.30 59 31.88 94 31.01 119 31.02 144 169 1941 20 31.07 45 31.06 70 31.10 95 31.77 1201 31.06 145 170 195 21 31.52 46 31.21 71 31.10 96 31.02 121 30.66 t46 1T1 196 22 31.55 47 30.40 72 31.82 97 ( 31.04 122 31,90 147 172 197 23 31.47 48 30.40 73 31.74 98 31.07 123 31.69 148 173 1 ~ 24 31.02 49 30.40 T4 31.03 99 31.02 i 24 34.99 149 1741 199 25 31.04 50 31.03 ! 75 31.06 t0D 31.02 125 31.08 1501 1751 200 TOt 777.33 Tot 775.99 Tat 781.75 Tot 781.01 Tot 779.48 TOt 471.64 Tot TOTAL LIrNGTH TH[S PAGE = 438720 DtRECT1ONS: TOTAL JOINTS THIS PAGE = 14Q (r~ _. TOL ~'ECc1'`urEt? IJ6t"~;'::G_tli~ tCt:~tE, ~ti7,d ,i;'1~~ -~~} ~ ~N~ Jun 251 ~ U7.~4a PDS Prudhoe ~ 19{776~Z314 P~3 ARCO ALASKA ING 1 TUBING TALLY PAGE: 2 of 2 _WELL NUMBER: 1C-124 (G3) Kuparuk River Unit RIG: Nord Rig ~2 TUBING DESCRIPTION: 2-718"", 6.5At, L-80, ABM-EUE, Non-Coated -Range 2 -Class A DATE: 02108!9$ Column 9 Calumn 10 Column 11 Column 12 Column 13 Column 14 Column 15 Column 16 No Feet No Fast No Feet No Feet No Feet No Feet Na Feet Na Feet 201 226 251 276 301 326 351 376 202 1 227 252 277 302 327 352 377 203 22B 253 278 303 328 353 378 204 229 254 279 304 329 1 354 379 205 230 255 280 305 330 1 355 380 206 231 256 281 306 331 356 387 ( 207 232 257 282 307 332 357 ) 382 208 233 258 1 283 308 333 358[ 383 209 734 259 284 309 334 3591 384 210 235 280 1 285 310 335 360 385 211 236 261 285 311 . 33S 367 1386 212 237 262 287 312! 337 362 387 213 138 263 288 3131 338 363 388 214 239 •264 269 314 339 364 389 215 240 265 290 315 340 365 390 216 241 266 29t 376 347 366 391 217 2 267 292 317 342 387 392 218 243 268 283 1 318 343 368 393 279 2 268 294 ( 319 344 368 394 220 24S 270 2951 X 320 345 37d 395 221 246 271 296 311 346 371 396 222 247 272 297 322 347 372 X 397 2231 248 ZT3 2981 323 348 3731 398 224 249 274 199 324 349 3741 399 225 250 275 300 325 3501 375 400 Tot Tot ] ~ Tot TOTAL LENGTH THIS PAGE TOTAL LENGTH = 4367.20 TOTAL JOINTS THIS PAGE T07AL JOINTS ~ 140 TOt lot TOL tOi Average Jt = 31.19 !=c_tZ~~-La N~i'?F '1F_~iE] 1~~:gib ~sd 1'i.;,5 ~u~} 2v 1 G {3l 44a PD8 Prudhae CASING ! TUBING t LINER DETAIL 7-5f8" Surface/Production Casing ARCO Alaska, Inc. S~~siytar~, of Atbntic t7'ehTeki Gampary Ca : =~R= 19x75314 ,' p.4 West Sak, Kuparvk WELL: 1 t7-124 DATE; 114198 1 flF i PAGES ,: ITEMS E COMPLETE DESGRIP?ION OF EflUtPMENT i4UN LENGTH DEPTH TOPS IRKS tc Landm Rir 40.56 ;VETCO-Gray Fl,:ted Mandra Casin Han er 2.1g X0.88 43 Jts 7-5r8", 29.7#, L-8C, ABM-BTC Casin --#76-#118 176p,rb i 42.84 Joint '$' 7-518". 2g.7#, ! -80, ABM-BTC Casin - t3aker Locked 41.56 93G3.&D Gemoco TS4 Cementin Sta a Collar 2,35 1gg5.15 Joint A' 7-5t8"', 25.7#, 8G. At31~4-BTC Casin -Baker Locked 42.61 1848.G1 59 JtS r'-5I8°, 29.7#. ~-8G. AB1,".-BTC Casin-#1775 2E26.56 1 &90.E2 AAarker Pu Jt: 7-518", 29.7#, L-80, ABM-8TC Casin 79.68 4317.18 Marker Pu Jt: 7-518".29.7#, L-80, ABM-t3TC Casin 19.9G 4336.84 13 Jts 7-518", 29.7#, L-S0 A13b1-BTC Casin --#4-#i8 548.05 4356.?= Gemoco~lnsert Shut-0ff Baffle 49~,7g ,1t 7-5(8", ;e9.7#, L-s0, ABPl,-BTC Casir --7r3 42.10 4904.?9 Ger~c~ ='so8t Collar 1.28 4946.95 _ 1 ut ~ 7-5/t?". 29.'it, L-E0, A.3r~1-BTC Casir -Baker Lacked--#2 41.00 494823 1 Jt 7-5,'8" 29.7#, L-80, ABM-BTC Casing--xtl 42.50 ! 49$9.2.°. Gemeco F'oat S~oe '.SD 5031,73 5033.23 TD = 5047' MD ^-14' Rathole - __ E ljakerLock fo Tap of Bathe Collar Joint (LC), plus Stage Co/1ar fo Jfs A' & 'B' _ ___ _ __ _ __ v w vav :yen vs +v aror u~mrLw Install a Centralizer on eve 3rd 'oinf fo Surface, aj, /nstal/ a Centralizer on a Sto Rin on BakerLock Jts ;4' ~ '8' Run Double-Pu Marker Joint between Jis #16 8 #17. Run S e Collar 8 BakerLock JLS A' & 'B' between Jfs #75 & #76. Run Fluted Casin Nan er on To of Jt #718. Leave 5 Jts in the Shed (Jts #119 thru #923 . ~u-~,.orna, vu+~iy rvGiyn[5 wiUt DICG!CS:GvURiF U~. 1L~IS7t tin /47![~ tiIGGtCS Kan i12 Oln?S Of G$Sltlq {.`t4S Marker .latnt. Drifter casing vlltis 8.?50" plastic rabbit Used Arctic Grade API ~9od'Rad No Lead thread ~:ompourxal ar, alt connections (National = BQL 2000). h!ace up cornect`ors to base Gf =riangie stare __._ Parser Rig #245 Orliiir)g SUC9N1SOf. G.R. Whitlock ?E1EIit`P E~r~i~`~`~l~l~t 1~~:-1E ='_1a' '~r5 ~C~~. =~~R~' Jun'?51(~ J7:45a PITS Prudhoe ~ ?9076314 i p.5 ARGO ALASKA INC CASING TALLY PAGE: 1 of 1 WELL NUMBER: 1D-124 WestSak, Kuparuk RIG: Parker Rig#245 CASING DESCRIPTION: 7-518", 29.70#. L-80, ABM-BTC -Range 3 -Class A DATE: 114198 Column 1 Column 2 Column 3 Column 4 Column 5 ' Column 6 Column T ~ Column 8 No Feet No Feet ~ No Feet No Feet No Peet No Feet No Feet No Feet :1 id 42.SC1 26 41. i 9 a 51 »2.42 7;6? 42.13 1 D1 42.4G 126 ~ 151 176 ' c2~ 41.G0 27 42.18 "~: 41 A3 77 41.28 102 35.41 127 J 152 1177 ~~ , d2 15 ,"211' 40.03 53 42 3C 78 42.04 '103 36J0 128 _ ~ 153 178 '~ 4.t~9 29 42.13 54 41.18 ~9 i 40.91 i D4 42.63 129 154 i 179 `t _~ ; 41.87 30 36.25 x;55 42.48 80 39, 84 105 42.61 130 155 " 180 I~ ~ ~,' ~ 42,So" ~~ 40.53 56 ~ 39.E9 81 42.54 '~0~ 42.46 131 ~ 156 ' 181 ~ ~ ~sii. 42..16 32 41.3 7 57 42,03 _8iz- 42.61 107 42.83 132 157' 1 i 82 I ~{`~ 42.20 33 ' 4'.87 ~ _ 40,63 83 42.60 108 41.25 133 158; 183 42,28 ~:4~ =1 ?1 59 j 42.57 84 4221 42,62 134 1591 184 a'1(1 41.53 35 40.E3 60 42.&G x.135' 38.21 i 110 42.20 135 160 185 '!$1i~ 42.75 36 40.fr2 pt"g~~ 42.4G 86 41,19 ? 111 42.6' 136 161 186 ~92i~ 42.31 ~:~!~; 4~J.61 62 42.44 $7 42.83 1t~12 42.45 137 i62 187 ti 42.60 38 37,'9 63 40,55 .88 34.53 j 113 36.99 ~ 138 183 188 42,27 39 "x6.72 '' _; 41.36 84 4Q 18 114 38.09 ! 139 1 fi4 189 i:~5! 40.85 ~?t~; 40:62 6S 42.51 90 42.30 I~;11v" »D.87 ; 140 165 190 B` 41.93 41 40.84 66 42.55 ~ , 9:1 ~+ 41.34 116 37.E0 i 141 166 191 ~~;; 4'.88 42 37.73 ±$7' 42.00 j 92 41.46 117 i 42.42 142 167 192 16 39.39 ;~~~; 42.56 68 42.5A ~ 93 f2.31 118 42.62 143 168 193 '1~.4 ~ 40.21 44 4) .24 ~ 69 37.48 94 ~ 42.62 #~$ i 4~~ 144 ` 169 194 20 40.95 45 41.5' , ~70~ 42.57 j 95 ~ 3T °0 1-20' ~.3-a.B 1451 170 ` 195 21 42.34 °, ~~ 42.79 71 42,52 9fi L2! 47 4~ 42:5.5 i46 _ _ 171 _ 196 .22' 39.69 47 43.08 ' T2 41.53 ;97' c2.61 ,As3-~. 147 112 ~ ! 197 23 39.35 48 42.05 7~?<` 42.59 98 35,68 ;~3 ;48~EJ 148 173 ' 198 24 42.'.3 j fat ; 42.52 74 42.55 99 42.08 124 149 174 I 199 s` , ~; 35.43 50 42,59 75 44.b2 ;'~00~ 42,23 125 150 175 200 t OL WS.~~ ! OL 7 UZ7 .1b t Ot ~ U4~ :.4 TOI 1U2o.OJ TOL 940.17 Tot TOt TOt TOTAL LENGTH THIS PAGE = 54ov.S4 ~F..AVc OUT Jts #119 thru #123 DIRECTIONS: Landtn Joint = 45.55' TOTAL JOIN75 TH1S PAGc = 123 Float Shce = i .50' Float Cotlar = ' .L8' Average ,~t = 41.19 P~18rker Joint = 19.66' Taa + ' 9.90' Bottom Gemcco 754 Sta e Toot = 2.85` Fluted Mandrel Han er = 2.18' Jt'A' = 42.61', Jt "B' = 41.56' RK8 to Landinc Rina = 40.66' THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON'OR BEFORE JANUARY 03. 2001 M C:LORIIM~ILM.DOC PL A T E IA L IS M A R E 'W UNDER K E R. 197-217-0 KUPARUK RIV U WSAK 1D-124 50- 029-22833-00 ARCO MD 05047 TVD 04262 ~C-ompletion Date: ~2'/10/98 Completed Status: 1-OIL Current: T Name Interval Sent Received T/C/D ~-sPE~R~ ~P~/~R/E~ .................................................................................................................................................................................. OH 1/28/98 1/28/98 D 8241 L DGR/EWR4-TVD ..Ft~A L 121-4262 OH 1/28/98 1/28/98 L FLOW-TEM/PRES ~AL i20-4200 '-~/~C{/c~' CH 5 7/9/98 7/13/98 L GR/CCL DEPTH DEU 'FINAL 121-5047 OH 1/28/98 1/28/98 D R MWD SRVZ ~Y 0-5047. OH 1/29/98 2/4/98 Daily WellOps /.~/c/~__ a}/(,/c{f Are DryDitchSamplesRequired? yes Was the well cored? y~- Analysis Description Comments: Thursday, February 03, 2000 Page 1 of 1 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 26, 1998 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 1D-124 (Permit No. 97-217) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on West Sak 1D-124. If there are any questions, please call 265-6890. Sincerely, · T. W. Mc Kay Senior Drilling Engineer Kuparuk Development TWM/skad STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well OIL ~1 GAS ~] SUSPENDED k-~ ABANDONED~ SERVICE E~ 2 Name of Operator '7 Permit Number ARCO Alaska, Inc 97-217 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-029-22833 4 Location of well at surface ,- . .? 9 Unit or Lease Name 847' FNL, 2556' FWL, Sec. 23, T11N, R10E, UM ' · ' · ~ . · KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) I 6 Lease Designation and Serial No. West Sak Oil Pool RKB 41', Pad 70'I ADL 25650 ALK 468 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 115 Water Depth, if offshore 16 No. of Completions 02-Jan-98 04-Jan~98 10-Feb-98J NA feet MSL 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where SSSV set I 21 Thickness of permafrost I 5047' MD & 4262' TVD 4905' MD & 4128' TVD YES M NO U NA feet MD 1682' APPROX 22 Type Electric or Other Logs Run GR/Res 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE VVT GRADE TOP BTM HOLE SIZE CEMENT RECORD 16" 62.58# H-40 SURF. 121' 24" 9 cu )/ds High EDdy 7.625' 29.7# L-80 SURF. 5033' 9.875' 499 sx AS III, 334 sx Class G, 60 sx AS I 24 Pedorations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2.875" 4254' 4677', 4564', 4490', 4395', 4294' 4356'-4388' MD 3613'-3643' TVD 12 spt 4420'-4484' MD 3673'-3732' TVD 12 spt 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC 4514'-4560' MD 3761'-3804' TVD 12 spt DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 4590'-4672' MD 3832'-3909' TVD 12 spt 4356'-4388' MD D-sand: 77880# 16/20 proppant SWS 4.5" HSD fCP w/ultro-pock 24 GM RDX chorges 4420'-4484' B-sand: 124,407# 16/20 proppant 4514'-4560' A-3 sand: 101,6434¢ 16/20 proppant 4590'-4672' A-2 sand: 104,493~ 16/20 proppant 27 PRODUCTION TEST Date First Production02/15/1998 IMeth°d °f Operati°n (Fl°wing' gas lift' etc')EsP Date of Test Hours Tested PRODUCTION FO OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO 02/23/1998 6.00 TEST PERIOI: 50 0 5 0I 7 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 160 -15 24-HOUR RATE: 202 1 23 0° 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. N/A INAL Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. ,30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top West Sak Sand 4354' 3611' Base West Sak Sand 4810' 4038' Annulus left open - freeze protected with diesel. 31. LIST OF ATTACHMENTS Summary of Daily Drilling Reports, Directional Survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. .~~~ Prepared by Name/Number Sharon Allsup-Drake/263-4612 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form f0-407 Date: 2/18/98 ARCO ALASKA INC. WELL SUMlVLARY REPORT Page: 1 WELL:iD-124 RIG:PARKER WELL_ID: AK9037 TYPE: AFC: AK9037 AFC EST/UL:$ 1806M/ 2168M STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT BLOCK: SPUD:01/02/98 START COMP:02/02/98 FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029-22833-00 01/02/98 (D1) TD: 205' (205) SUPV:GRW 01/03/98 (D2) TD: 2401' (2196) SUPV:GRW 01/04/98 (D3) TD: 5047'(2646) SUPV:GRW 01/05/98 (D4) TD: 5047'( SUPV:GRW o) 01/06/98 (D5) TD: 5047'( SUPV:DEB o) 01/07/98 (D6) Tm: 5047'( SUPV:DEB 0) MW: 8.9 VISC: 360 PV/YP: 43/47 APIWL: 9.5 DRILLING Safety meeting. Move rig from 1D-117 to 1D-124. Accept rig at 1430 hrs. 1/2/98. N/U diverter system and function test. Drill from 121' to 205' MW: 9.2 VISC: 306 PV/YP: 30/50 DRILLING AT 3500' Drill from 205' to 2401' APIWL: 7.2 MW: 9.2 VISC: 275 PV/YP: 35/49 RIH W/HOLE OPENER Drill from 2401' to 5047' APIWL: 7.0 MW: 9.4 VISC: 90 PV/YP: 23/23 APIWL: 7.0 CEMENTING POOH, tight 1170' to 990' Safety meeting. Run 7-5/8" casing to 5033' MW: 8.8 VISC: 42 PV/YP: 25/10 APIWL: 7.0 DISPLACE TOP TO DIESEL Pump first and second stage cement. NU BOPE. Test BOPE to 300/2000 psi, OK. Drill cement from 4606' to 4835' and continue to clean out. MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 RIG RELEASED (MOVED TO 1D-109) Continue drilling cement from 4835' to plug on baffle at 4905' PBTD. ND BOPE. NU tree and test to 5000 psi. Release rig @ 1630 hrs. 1/17/98. Date: 2/18/98 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 REMEDIAL AND COMPLETION OPERATIONS WELL:iD-124 RIG:NORDIC WELL_ID: AK9037 TYPE: AFC: AK9037 AFC EST/UL:$ 1806M/ 2168M STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT BLOCK: SPUD:01/02/98 START COMP:02/02/98 FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029-22833-00 02/02/98 (C7) TD: 5047' PB: 0' SUPV:DLW MOVE RIG FROM 3Q-14 TO iD Move rig from 3Q-14 to 1D-124. MW: 0.0 02/03/98 (C8) TD: 5047' PB: 4905' SUPV:DLW POOH F/2200' MW: 8.7 KCL Continue turn key rig move from 3Q to iD. Accept rig @ 0830 hrs. 2/3/98. N/D tree and N/U BOPE and test to 250/3000 psi. 02/04/98 (C9) TD: 5047' PB: 4905' SUPV:DLW RIH W/TCP GUNS Circulate hog wash. MW: 8.7 KCL 02/05/98 (Ci0) TD: 5047 ' PB: 4905' SUPV:DLW POOH CLEAN OUT 6.75" MILL MW: 8.7 KCL RIH w/TCP guns to perforate. Perforate intervals 12 spf. 4356'-4388', 4420'-4484', 4514'-4560' & 4590'-4672'. Ail shots fired. 02/06/98 (Cll) TD: 5047' PB: 4905' SUPV:DLW SET TOP PACKER MW: 8.7 KCL Continue to clean out. RIH with sump packer and set top of packer @ 4677' 02/07/98 (C12) TD: 5047' PB: 4905' SUPV:DLW COMPLETED FRAC & PACK MW: 8.7 KCL Set isolation packers @ 4564', 4489' & 4395' Frac pack A2 zone 4590'-4672' Frac A3 zone 4514'-4560' Date: 2/18/98 02/08/98 (C13) TD: 5047' PB: 4905' SUPV:DLW ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 FRAC 'D' ZONE 4356'-4388' MW: 0.0 KCL Frac B/A4 zone 4420'-4484'. RIH on 3.5" workstring. Circulate crude oil f/wellbore. Oil migrating thru 9.2 ppg brine. Baker smart collet malfunctioned stuck in run thru position. 02/09/98 (C14) TD: 5047' PB: 4905' SUPV:DLW RIH W/2-7/8" ESP COMPLETI MW: 9.2 KCL RIH w/workstring to frac 'D' zone 4356'-4388' 76,0009 of sand behind pipe. R/U to run ESP completion. 02/10/98 (C15) TD: 5047' PB: 4905' SUPV:MC NU TREE MW: 8.7 BRINE Run in hole with 2-7/8" completion assembly and ESP cable and heat trace. 02/11/98 (C16) TD: 5047' PB: 4905' SUPV:MC RELEASED RIG @ 1400 HRS 2 MW: 8.7 BRINE NU tree, test tree, ESP and heat trace. Freeze protect well.Secure well and rig down. Release rig @ 1400 hrs. 2/11/98. End of WellSummary for Well:AK9037 ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(1D-124(W4-6)) WELL 1 D-124 JOB SCOPE FRAC, FRAC SUPPORT JOB NUMBER 0206981658.3 DATE DALLY WORK UNIT NUMBER 02/07/98 PUMP FRAC & PAK ON "A-2 & A-3 SANDS KEY PERSON DS-YOKUM DAY OPERATION COMPLETE SUCCESSFUL I YES YES Initial Tbg Press I Final Tbg Press I Initial Inner Ann 0 PSII 0 PSII 0 PSI DAILY SUMMARY SUPERVISOR JOHNS Final Inner Ann I Initial Outer Ann I Final Outer Ann 0 PSII 0 PSII 0 PSI FRAC'ED "A-2" SANDS WITH 95,000# OF 16/20 PROPPANT TO PERFS. FRAC'ED "A-3" SANDS WITH 101,643# OF 16/20 PROPPANT TO PERFS. TIME LOG ENTRY 07:00 MIRU DOWELL FRAC AND APC SUPPORT TO NORDIC RIG FOR FRAC & PAK. 11:27 HELD JOB SAFETY MEETING ON RIG FLOOR. 12:52 PUMP IMPULSE TEST WITH 20 BBLS DIESEL AT 18 B'PM AND 3564 PSI. SHUT DOWN FOR ISIP 830 PSI. 13:55 PUMP BREAKDOWN WITH 200 BBLS 50# HEC , 20 BPM 3352 PSI. FLUSH WITH 50 BBLS DIESEL· SHUT DOWN FOR ISIP 1157 PSI. 15:01 PUMP DISPLACEMENT AND DATA FRAC & FLUSH WITH DIESEL. 100 BBLS HEC AND 48 BBLS DIESEL. 2787 PSI · SHUT DOWN FOR ISIP 1094 PSI. 16:17 PUMP 22 BBLS PAD OF 50# HEC 5 BPM AND 1652 PSI. 16:23 PUMP 104,493# OF 16/20 PROPPANT FROM 2 TO 10 PPA TO "A-2" SANDS. SCREENED OUT WITH 7.6 PPA SLURRY AT PERFS. 95000 # TO PERFS. REVERSED OUT SLURRY FROM TUBING. 16:58 RIG FLOOR REPOSITIONED FRAC TOOL TO "A-3" SANDS. 18:21 PUMP "A-3" IMPULSE TEST WITH 20 BBLS DIESEL AND 3575 PSI. 19:23 PUMP BREAKDOWN WITH 150 BBLS 50# HEC, 20 BPM AND 3337 PSI. PUMP FLUSH WITH 50 BBLS DIESEL. SHUTDOWN FOR ISIP 1153 PSI. 20:23 PUMP DISPLACEMENT, DATA FRAC AND FLUSH. 75 BBLS HEC AND 40 BBLS DIESEL. 21:45 PUMP PAD 25 BBLS HEC, 5 BPM AND 1684 PSI. 21:49 PUMP 16/20 PROPPANT FROM 2PPA TO 10 PPA. 20 BPM AND SCREENED OUT WITH 6600 MAX PRESSURE. PUMPED 101,643 # TO PERFS AT 7.9 PPA. 22:27 REVERSED SLURRY OUT OF TUBING, AND REPOSITIONED FRAC TOOL TO FRAC "B" SANDS. ARCO Alaska, Inc. WELL 1 D-124 DATE 02/08/98 DAY 1 JOB SCOPE FRAC, FRAC SUPPORT DAILY WORK PUMP FRAC&PAK "B" SANDS OPERATION COMPLETE I SUCCESSFUL YESI YES Initial Tbg Press I Final Tbg Press Initial Inner Ann 0 PSII 0 PSI 0 PSI DALLY SUMMARY KUPARUK RIVER UNIT WELL SERVICE REPORT K1(1D-124(W4-6)) JOB NUMBER 0206981658.3 KEY PERSON DS-YOKUM Final Inner Ann 0 PSI UNIT NUMBER SUPERVISOR JOHNS Initial Outer Ann I Final Outer Ann 0 PSII 0 PSI IPUMPED FRAC & PAK ON "B" SANDS , WITH A TOTAL OF 124,407# 16/20 PROPPANT TO 10 PPA TO PERFS. PUMPED TO COMPLETION AS DESIGNED. TIME LOG ENTRY 00:31 PUMPED IMPLUSE TEST WITH 20 BBLS DIESEL AT 20 BPM AND 3800 PSI. SHUT DOWN FOR ISIP 1094 PSI. 01:39 PUMPED BREAKDOWN WITH 50#HEC AT 20 TO 15 BPM, 300 BBLS AND 4253 TO 2683 PSI. PUMP FLUSH WITH 49 BBLS DIESEL. SHUT DOWN FOR ISIP 1158 PSI. 03:07 PUMP DISPLACEMENT, DATAFRAC AND FLUSH W/39 BBLS DIESEL. 2271 PSI. SHUT DOWN ISIP 1181PS1. 04:34 PUMP 30 BBLS PAD OF 50# HEC, 15BPM AND 1630 PSI. 04:39 PUMPED 124,407# 16/20 PROPPANT FROM 2 PPA TO 10 PPA TO PERFS IN "B' SANDS, 15BPM AND 2788 PSI. WENT TO FLUSH WITH DIESEL. WENT TO CIRCULATE POSITION WITH BAKER FRAC & PAK TOOL, TO DEHYDRATE SLURRY FOR A PAK OF PROPPANT IN "B" SANDS. 05:34 REVERSED OUT FLUIDS IN THE TUBING. NORDIC PULLING FRAC & PAK TOOL FOR EROSION INSPECTION. ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(1D-124(W4-6)) WELL 1 D-124 JOB SCOPE FRAC, FRAC SUPPORT JOB NUMBER 0206981658.3 DATE DALLY WORK UNIT NUMBER 02/09/98 PUMP FRAC & PAK TO "D" SANDS KEY PERSON DS-YOKUM DAY OPERATION COMPLETE I SUCCESSFUL 2 YES I YES Initial Tbg Press I Final Tbg Press I Initial Inner Ann 0 PSII 0 PSII 0 PSI DAILY SUMMARY SUPERVISOR JOHNS Final Inner Ann ] I 0 PSI Initial OuterAnn ] 0 PSI I Final Outer Ann 0 PSI PUMPED FRAC & PAK IN "D" SANDS WITH 76,3044f 16/20 PROPPANT TO 8 PPA TO PERFS. TIME LOG ENTRY 03:00 MI DOWELL FRAC EQUIP., AND APC VAC TRUCK 03:30 HELD JOB SITE SAFETY MEETING ON NORDIC RIG FLOOR. 04:30 PRIME PUMPS, PUMP 20 BBLS DIESEL FOR IMPULSE TEST, 20 BPM AND 4100 PSi. 05:38 PUMPED BREAKDOWN WITH 300 BBLS OF 50# HEC., 15 BPM AND 4123 TO 2146 PSI. FLUSH WITH 48 BBLS DIESEL. SHUT DOWN FOR ISIP. 06:45 PUMPED DISPLACEMENT, DATAFRAC AND FLUSH. 150 BBLS HEC AND 38 BBLS DIESEL. 5 TO 15 BPM AND 2500 PSI. SHUT DOWN FOR ISIP AND CLOSURE CALCULATIONS. 08:00 PUMPED 35 BBLS PAD WITH 5 BPM AND 1515 PSI. 08:07 PUMPED 77,880# 16/20 FROM 2 TO 9 PPA, PLACED 76,304 # PROPPANT IN PERFS. 08:45 PUMPED COMPLETION, AND DEHYDRATED PAK WITH BAKER TOOL IN CIRCULATE POSITION. · SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 1 ARCO ALASKA, INC. WEST SAK / iD-i24 500292283300 NORTH SLOPE BOROUGH COMPUTATION DATE: 1/19/98 DATE OF SURVEY: 010498 MWD SURVEY JOB NUMBER: AKMM80064 KELLY BUSHING ELEV. = 111.30 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. .00 .00 -111.30 0 0 N .00 E .00 121.00 121.00 9.70 0 0 N .00 E .00 288.19 288.18 176.88 0 55 N 36.36 E .56 559.72 559.66 448.36 1 13 N 2.48 E .25 740.29 740.19 628.89 1 14 N 78.61 W .89 .00N .00E .00 .00N .00E .00 1.09N .80E -1.07 5.76N 2.24E -3.72 8.06N .40E -2.58 920.34 920.05 808.75 3 50 S 74.69 W 1.55 1011.26 1010.49 899.19 7 45 S 68.97 W 4.34 1104.65 1102.70 991.40 10 26 S 67.72 W 2.90 1200.17 1196.12 1084.82 13 30 S 68.83 W 3.21 1294.83 1287.53 1176.23 16 33 S 68.46 W 3.22 6.85N 7.32W 5.18 3.85N 15.98W 14.34 1.62S 29.70W 29.02 8.94S 48.13W 48.74 t7.89S 70.99W 73.18 1391.04 1378.90 1267.60 19 53 S 69.37 W 3.47 1486.12 1467.49 1356.19 22 40 S 70.32 W 2.95 1581.79 1554.76 1443.46 25 41 S 71.82 W 3.22 1675.39 1638.01 1526.71 28 41 S 72.78 W 3.24 1771.31 1720.40 1609.10 32 52 S 71.30 W 4.43 28.69S 99.07W 103.14 40.56S 131.46W 137.54 53.24S 168.53W 176.66 66.23S 209.28W 219.40 81.40S 255.95W 268.44 1867.46 1799.12 1687.82 37 10 S 72.59 W 4.54 1962.47 1872.78 1761.48 41 9 S 71.87 W 4.22 2057.55 1942.20 1830.90 45 2 S 73.69 W 4.29 2152.67 2006.75 1895.45 49 27 S 73.'22 W 4.66 2338.54 2127.30 2016.00 49 40 S 74.20 W .42 98.46S 308.40W 323.55 116.78S 365.52W 383.50 135.97S 427.56W 448.42 155.87S 494.50W 518.25 195.55S 630.29W 659.71 2622.36 2310.49 2199.19 49 55 S 74.69 W .16 2907.99 2494.51 2383.21 49 50 S 77.69 W .80 3188.65 2672.83 2561.53 51 16 S 74.84 W .93 3379.81 2795.18 2683.88 49 8 S 77.16 W 1.45 3471.94 2857.15 2745.85 46 18 S 75.45 W 3.36 3563.52 2921.87 2810.57 43 45 S 77.71 W 3.29 3663.67 2996.85 2885.55 39 15 S 76.67 W 4.56 3758.58 3072.40 2961.10 35 12 S 77.28 W 4.27 3852.30 3151.09 3039.79 30 32 S 77.92 W 4.99 3946.21 3233.80 3122.50 25 55 S 78.70 W 4.95 253.68S 839.13W 876.49 305.81S 1051.19W 1094.74 357.31S 1261.69W 1311.31 392.89S 1404.16W 1458.09 409.00S 1470.39W 1526.20 424.06S 1533.40W 1590.93 438.75S 1598.10W 1657.19 451.70S 1654.03W 1714.53 462.64S 1703.70W 1765.31 471.66S 1747.19W 1809.61 4042.46 3321.54 3210.24 22 37 S 75.69 W 3.66 4138.42 3410.39 3299.09 21 44 S 75.50 W .92 4326.81 3585.72 3474.42 21 10 S 74.41 W .36 45i8.74 3765.23 3653.93 20 15 S 74.71 W .48 4709.86 3944.67 3833.37 20 0 S 74.13 W .17 480.36S 1785.77W 1849.10 489.37S 1820.85W 1885.32 507.25S 1887.41W 1954.23 525.33S 1952.86W 2022.13 543.00S 2016.23W 2087.92 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 2 ARCO ALASKA, INC. WEST SAK / 1D-124 500292283300 NORTH SLOPE BOROUGH COMPUTATION DATE: 1/19/98 DATE OF SURVEY: 010498 MWD SURVEY JOB NUMBER: AKMM80064 KELLY BUSHING ELEV. = 111.30 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 4898.26 4122.01 4010.71 19 27 S 74.44 W .30 4985.44 4204.39 4093.09 18 45 S 74.51 W .79 5047.00 4262.68 4151.38 18 45 S 74.51 W .00 560.23S 2077.46W 2151.52 567.87S 2104.95W 2180.05 573.16S 2124.03W 2199.85 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 2200.00 FEET AT SOUTH 74 DEG. 53 MIN. WEST AT MD = 5047 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 254.23 DEG. TIE-IN SURVEY AT SURFACE 0.00' MD PROJECTED SURVEY AT 5,047.00' MD SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 3 ARCO ALASKA, INC. WEST SAK / 1D-124 500292283300 NORTH SLOPE BOROUGH COMPUTATION DATE: 1/19/98 DATE OF SURVEY: 010498 JOB NUMBER: AKMM80064 KELLY BUSHING ELEV. = 111.30 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION .00 .00 -111.30 1000.00 999.33 888.03 2000.00 1900.70 1789.40 3000.00 2553.56 2442.26 4000.00 3282.55 3171.25 .00 N .00 E 4.37 N 14.61 W 124.43 S 389.40 W 321.42 S 1120.01 W 476.41 S 1769.41 W .00 .67 .67 99.30 98.62 446.44 347.14 717.45 271.01 5000.00 4218.17 4106.87 5047.00 4262.68 4151.38 569.12 S 2109.46 W 573.16 S 2124.03 W 781.83 64.38 784.32 2.50 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 4 ARCO ALASKA, INC. WEST SAK / tD-i24 500292283300 NORTH SLOPE BOROUGH COMPUTATION DATE: 1/19/98 DATE OF SURVEY: 010498 JOB NUMBER: AKMM80064 KELLY BUSHING ELEV. = 111.30 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 -111.30 .00 N .00 111.30 111.30 .00 .00 N .00 211.30 211.30 100.00 .11 N .08 311.31 311.30 200.00 1.39 N 1.03 411.33 411.30 300.00 2.70 N 1.99 E .00 E .00 .00 E .00 .00 E .01 .01 E .03 .01 511.35 511.30 400.00 4.73 N 2.19 611.37 611.30 500.00 6.85 N 2.28 711.39 711.30 600.00 7.94 N 1.02 811.43 811.30 700.00 8.05 N. 1.73 911.57 911.30 800.00 7.00 N 6.78 E .05 .02 E .07 .02 E .09 .02 W .13 .04 W .27 .14 1012.08 1011.30 900.00 3.80 N 16.12 1113.41 1111.30 1000.00 2.24 S 31.21 1215.80 1211.30 1100.00 10.29 S 51.61 1319.68 1311.30 1200.00 20.54 S 77.75 1425.61 1411.30 1300.00 32.90 S 110.38 W .78 .51 W 2.11 1.33 W 4.50 2.39 W 8.38 3.88 W 14.31 5.93 1533.87 1511.30 1400.00 46.83 S 149.40 1645.10 1611.30 1500.00 61.96 S 195.63 1760.51 1711.30 1600.00 79.54 S 250.43 1882.82 1811.30 1700.00 101.27 S 317.33 2014.51 1911.30 1800.00 127.35 S 398.87 22 33 49 71 103 .57 8.26 .80 11.22 .21 15.41 .52 22.31 .21 31.69 2159.67 2011.30 1900.00 157.40 S 499.60 2313.81 2111.30 2000.00 190.42 S 612.15 2468.33 2211.30 2100.00 222.49 S 725.49 2623.61 2311.30 2200.00 253.93 S 840.05 2778.93 2411.30 2300.00 284.77 S 954.82 148 202 257 367 .37 45.16 .52 54.14 .03 54.51 .31 55.28 .63 55.32 2934.06 2511.30 2400.00 310.11 S 1070.67 3090.85 2611.30 2500.00 338.07 S 1188.14 3249.68 2711.30 2600.00 369.41 S 1307.49 3404.25 2811.30 2700.00 397.04 S 1422.05 3548.82 2911.30 2800.00 421.84 S 1523.42 422 479 538 592 637 .76 55.13 .55 56.79 .38 58.83 .95 54.57 .52 44.57 3682.21 3011.30 2900.00 441.41 S 1609.41 3805.50 3111.30 3000.00 457.41 S 1679.64 3921.05 3211.30 3100.00 469.43 S 1736.16 4031.34 3311.30 3200.00 479.31 S 1781.56 670.91 694.20 709.75 720.04 33.40 23.29 15.55 10.29 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 5 ARCO ALASKA, INC. WEST SAK / 1D-124 500292283300 NORTH SLOPE BOROUGH COMPUTATION DATE: 1/19/98 DATE OF SURVEY: 010498 JOB NUMBER: AKMM80064 KELLY BUSHING ELEV. = 111.30 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 4139.40 3411.30 3300.00 4247.00 3511.30 3400.00 4354.24 3611.30 3500.00 4461.25 3711.30 3600.00 4567.85 3811.30 3700.00 489.46 S 1821.20 W 728.09 8.05 499.50 S 1859.64 W 735.70 7.60 509.92 S 1896.96 W 742.94 7.24 520.09 S 1933.66 W 749.95 7.01 529.82 S 1969.27 W 756.55 6.59 4674.34 3911.30 3800.00 4780.77 4011.30 3900.00 4886.90 4111.30 4000.00 4992.74 4211.30 4100.00 5047.00 4262.67 4151.38 539.68 S 2004.55 W 763.04 6.50 549.64 S 2039.57 W 769.47 6.42 559.22 S 2073.81 W 775.60 6.13 568.50 S 2107.21 W 781.44 5.84 573.16 S 2124.03 W 784.33 2.88 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11326 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 7/9/98 Field: Kuparuk (Reservoir Analysis Logs) Well Job # Log Description Date BL RF Sepia Floppy Disk 1 A-20 PRODUCTION PROFILE 980531 I 1 1D-10 ~- CBT 98051 8 I 1 1 D-124 FLOWING TEMP/PRESS 980524 I 1 1 D- 130 ~X, \ ~ - INJECTION PROFILE 980423 I 1 1 D- 133 FLOWING TEMP/PRESS 980524 I 1 1 E-23 ~\ \ L,r- INJECTION PROFILE 980523 I 1 2 A- 17 PRODUCTION PROFILE 980522 I 1 2 A- 19 PRODUCTION PROFILE 980510 I 1 2 D- 14 [.~\ (,_ WATER INJECTION PROFILE 9 8 0 5 31 I 1 2 D- 16 t,,X. I (,' -. WATER INJECTION PROFILE 980530 I 1 2 F- 02 t_t. t (- __ WATER INJECTION PROFILE 98052.. 8 I 1 .......................................... 2F-03 Iv~~ (_. -- WATER INJECTION PROFILE 980529 1 1 2 M- 23 TEMPERATURE SURVEY 980507 I 1 3 C- 04 PRODUCTION PROFILE 980505 I 1 3C-04 GAS LIFT SURVEY 980505 I 1 3F-06 GAS LIFT SURVEY 980512 I 1 3 F-06 PRODUCTION PROFILE 980512 I 1 3 F- 14 PRODUCTION PROFILE 98051 4 I 1 3K-27 GAS LIFT SURVEY 980504 I I _. 1D-09 CBT 98051 7 I I Please sign and return one copy of this transmittal to Sherrie at the above address, Thank you. DATE: D I:! I I--I-- I ~ O; S E I=!~/I C~ E S 29-Jan-98 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1D-124 Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey' 0.00' MD n/a' MD 5,047.00' MD (if applicable) Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) 5631 Silverado Way, Suite G · Anchorage, AJaska 99518 · (907) 563-3256 ° Fax (907) 563-7252 A Dresser Industries, Inc. Company WELL LOG TRANSMITTAL To: State of Alaska January. 28. 1998 Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs 1D-124, AK-MM-80064 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way,//G, Anchorage, AK 99518 1D-124: 2" x 5" MD Resistivity & Gamma Ray Logs' 50-029-22833-00 2" x 5" TVD Resistivity & Gamma Ray Logs: 50-029-22833-00 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company 0 F! I I--I--I r~J G WELL LOG TRANSMITTAL To: RE: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs January 28, 1998 1D-124, AK-MM-80064 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Jim Gah, in. Sperry-Sun Drilling Services. 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-029-22833-00 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company TONY KNOWLES, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 November 19. 1997 Mike Zanghi Drilling Superintendent ARCO Alaska. Inc. P O Box 100360 Anchorage, AK 99510-0360 Re' West Sak 1D-124(G33 ARCO Alaska. Inc. Permit No: 97-217 Sur. Loc.: 271 'FNL. 599'FEL. Sec. 23. T11N. R10E. UM Btmhole Loc: 862'FNL. 2588'FWL, Sec. 23. T1 IN. R10E. UM Dear Mr. Zanghi' Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you t¥om obtaining additional permits required bv law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test pertbrmed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice mav be given by contacting the Commission petroleum field inspector on the North Chairman BY ORDER OF THE COMMISSION dlffenclosures CC: Department of Fish & Game. Habitat Section w/o encl. Department of Envinomment Consen,ation xv/o encl. STATE OF ALASKA ~r,- ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Ddll X Reddll F.' lb Type of Well Exploratory [~ StratigraphicTest ~" Development Oil X Re-Entry F' Deepen ~ Service E~ Development Gas [~ Single Zone X Multiple Zone F~ 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 41', Pad 70' feet Kuparuk River Field 3. Address 6. Property Designation West Sak Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25650, ALK 468 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 271' FNL, 599' FEL, Sec. 23, T11 N, R10E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 816' FNL, 2529' FEL, Sec. 23, T11 N, R10E, UM 1 D-124 (G3) #U-630610 At total depth 9. Approximate spud date Amount 862' FNL, 2588' FWL, Sec. 23, T11 N, R10E, UM 11/24/97 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 1 D-05 4974' MD 2588' @ TD feet 27.5' @ 300' feet 2560 4189' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 900' feet Maximum hole angle 49.1 o Maximum surface 1400 psig At total depth (TVD) 1 840 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include sta~le data) 24" 16" 62.5# H-40 Weld 77' 41' 41' 118' 118' ___200 CF 9.875" 7.625" 29.7# L-80 BTC MOE 4933' 41' 41' 4974' 4189' 465 Sx Arcticset III & 320 Sx Class G & 60 sx AS I 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface Intermediate Production Perforatio;i:;;th: measuredORIGINAL true vertical 20. Attachments Filing fee X Property plat F- BOP Sketch X Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot [~ Refraction analysis [~ Seabed report [~ 20 AAC 25.050 requirements X 21. I hereby certify that the foregoing is true and correct to the best of mv knowledge Signed /' ~' C,'/,- ~ '~,~/tJ~¢¢//~// Drilling Superintendent f I Commission Use Only Permit Number APl nu~Coer I Approval date _ , ,,~ ,,,.~.~.¢ I See cover letter for ¢'..~--- ~. / ~ 1 50- ~, ~- ~ --- 2_.~ ? 3.~ I //--/7 - ~;/ I other requirements Conditions of approval Samples required E~ Yes J~ No Mud Icg required E Yes _~, No Hydrogen sulfide measures [~ Yes [~ No Directional survey required ,~ Yes [~ No Required working pressure for BOPE ~ 2M E~ 3M E~ 5M [~ 10M E 15M Other: Original Signed Bybyorderof .~ /¢., ,~,.? Approved by David W. -John~tnn Commissioner the commission Date // Form 10-401 Rev. 7-24-89 Submit in tr Drill and Case Plan for West Sak 1 D-124 (G3) Frac-Packed Producer General Procedure: , Excavate cellar, install cellar box, set and cement 16" conductor to +/- 110' RKB. Weld landing ring on conductor. 2. Move in / rig up drilling rig. Install diverter & function test same. . Spud and directionally drill 9-7/8" hole to desired target through West Sak interval. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. 4. Condition hole for casing, trip out. . Run and cement 7-5/8" 29.7# L80 BTC-MOD casing to surface, displace cement with mud. Perform stage job and top job as required. NOTE: Stage (DV) tool to be installed +/- 200 ft TVD below the base of permafrost interval. . Nipple down diverter and install wellhead. Nipple up BOP stack and pressure test same to 3,000 psi. , Pick up 6-3/4" mill tooth bit, 4-3/4" drill collars, and 3-1/2" drill pipe. Trip in and drill out stage collar. Clean out to PBTD. . Shut in BOP's and pressure test casing to 3,000 psi for 30 minutes per AOGCC regulations. Record results. . Swap well over to non-freezing completion brine. Filter brine to desired level. Trip out. 10. Nipple down BOP stack. Install production tree and pressure test same. Set back pressure valve. 11. Secure well and release rig. TAB, 9/25/97 Page 1 Completion Plan for West Sak 1D-124 {G3) Four-Stage, Single-Trip Frac-Pack Job, Frac-Packed Producer General Procedure: Well Preparation 1. Move in / rig up completion rig. . Pull back pressure valve, nipple down tree and install 11" 5M WP BOP stack and pressure test same. . Trip in with 6-3/4" bit and scraper on 3-1/2" workstring, and RIH to to PBTD. Pressure test 7-5/8" 29.7# L80 BTC-MOD casing. Perform casing wash and displace well to filtered brine. Pickle workstring as required. Filter brine to desired level. Trip out. , Rig up E-line unit, and make correlation run as required with GR/CCL to correlate logs for perforating. o Make up Baker sump packer on E-line. RIH and set same below A2 sands (bottom pay sands). Space out and set sump packer to position TCP guns accurately on next trip in. POOH with E-line. , Pick up TCP perforating gun string to perforate all West Sak intervals in one trip. Trip in with 3-1/2" workstring, and sting into sump packer seal bore. Locate TCP guns on depth. Set TCP packer above West Sak. , Use diesel cap and/or void tubing to achieve desired underbalance. Drop bar and fire guns. , Release packer and reverse out to clean brine. Kill well as required. TOH with TCP gun string. , Pick up gravel pack assembly, including wire-wrapped screens, gravel pack and isolation packers, blank pipe, frac-pack crossover tool, and other jewelry and trip in hole on 3-1/2" workstring. Screens and packers should be spaced out to allow for isolated frac-packs on the following four West Sak intervals in one trip: Stage 1: A2 Stage 2: A3 Stage 3: A4 + B Stage 4: D Page 2 Stage 1 10. Locate gravel pack string into seal bore of sump packer. Sting lower screen seal assembly and snap-latch into sump packer. Set all isolation packers. Rig up and pressure test frac equipment at surface. 11. Position frac-pack crossover tool as required. Perform data frac for Stage 1. 12. Using 16-20 mesh carbolite proppant, proceed to frac Stage 1 with the specified volume of proppant. 13. Shift crossover tool, and gravel pack Stage 1. 14. Shift gravel pack tools, and reverse out excess proppant and frac fluids. Stage 2 15. Re-position frac-pack tools to frac-pack Stage 2 interval. Rig up and pressure test frac equipment at surface. 16. Position frac-pack crossover tool as required. Perform data frac for Stage 2. 17. Using 16-20 mesh carbolite proppant, proceed to frac Stage 2 with the specified volume of proppant. 18. Shift crossover tool, and gravel pack Stage 2. 19. Shift gravel pack tools, and reverse out excess proppant and frac fluids. 20. 21. Stage 3 Re-position frac-pack tools to frac-pack Stage 3 interval. Rig up and pressure test frac equipment at surface. Position frac-pack crossover tool as required. Perform data frac for Stage 3. 22. Using 16-20 mesh carbolite proppant, proceed to frac Stage 3 with the specified volume of proppant. 23. Shift crossover tool, and gravel pack Stage 3. 24. Shift gravel pack tools, and reverse out excess proppant and frac fluids. Page 3 Stage 4 25. Re-position frac-pack tools to frac-pack Stage 4 interval. Rig up and pressure test frac equipment at surface. 26. Position frac-pack crossover tool as required. Perform data frac for Stage 4. 27. Using 16-20 mesh carbolite proppant, proceed to frac Stage 4 with the specified volume of proppant. 28. Shift crossover tool, and gravel pack Stage 4. 29. Shift gravel pack tools, and reverse out excess proppant and frac fluids. 30. Release frac-pack running tools and trip out of well. At this point, the flow conduit inside the screens from the sump packer to the upper packer should be free of sand and any plugs. Rathole should be available below sump packer. 31. Circulate well to clean brine. TOH with workstring. Change rams to 2-7/8" and pressure test same unless VBR's are available. 32. Pick up Centrilift ESP on 2-7/8" production tubing. 33. Run in well with ESP pump with power cable and data gathering information wire attached to tubing. 34. Attach Raychem heat trace cable to tubing at pre-determined depth to position bottom of heat trace below permafrost, and spaced out correctly to avoid surface splicing of heat trace cable. 35. Position ESP at desired depth, set tubing hanger and run electrical penetrators through same. 36. Make surface electrical connections as required, and set back pressure valve in tubing hanger. 37. Nipple down BOP stack, and nipple up production tree. Pressure test production tree. Secure well. 38. Release rig and turn well over to production. TAB, 9/25/97 Page 4 DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS & DRILLING AREA RISKS West Sak 1 D-124 (G3) Drillin.q Fluid Type Extended Bentonite Slurry Drilling Fluid Properties: Property Density Plastic Viscosity Yield Point Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to TD Initial 8.8-9.0 ppg 4O 15-45 5-20 10-30 8-15 8.0-10.0 4-6 % Spud to TD Final 9.6-10.0 ppg 35 20-35 5-15 10-35 5-10 8.0-9.5 8-12% Drilling Fluid System: Tandem Brandt Scalping Shale Shakers Triple Derrick Flow Line Cleaners Solids Processing System to Minimize Drilling Waste Desander, Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Mud Hoppers with Mixing Pumps *Spud mud should be adjusted to a FV between 150 - 250 sec/qt to drill gravel beds. Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Only one hole section will be drilled in this well. This single hole section will be drilled using a diverter system only for well control. A combination surface / production casing string will be run at total depth (TD). This combination surface / production casing will be cemented to surface using a stage (DV) collar. The stage collar will be placed approximately 200 feet TVD below the base of the permafrost interval. Page 1 MASP (Maximum Anticipated Surface Pressure): Since a separate string of surface casing is not planned for the West Sak 1D-124 (G3) well, there is no surface casing to be drilled out below requiring a BOP stack to be utilized. The combination surface / production hole to be drilled from surface through the West Sak pay zone can safely be drilled using a diverter system only for well control purposes. Based on actual well test data from the nearby WS1-01 well, expected reservoir pressures in the West Sak sands in the 1D pad area vary from 0.43 to 0.46 psi/fi, or 8.2 to 8.8 ppg EMW (equivalent mud weight), depending on the 'I-VD of the sand layer being evaluated. Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 9.7 ppg can be predicted as a maximum mud weight required to safely drill this formation, assuming a TVD of 3,581' MD/I'VD. Experience in the area has proven that these zones can be safely drilled using a diverter system only for well control purposes. The rig diverter system will be filled with water or mud and function tested prior to spudding the well. Since the combination surface / production casing will not be drilled out, leakoff test and MASP calculations are not necessary for drilling ahead. However, MASP calculations for cased hole operations are in order. Calculating MASP based on the highest recorded reservoir pressure from the WS1-01 well, and assuming a gas gradient of 0.11 psi/fi from the West Sak base in the West Sak 1D-124 (G3) well to surface, the following MASP can be computed: MASP = (4,001 fi)(0.46 - 0.11 psi/fi) = 1400 psi Based on this calculation for MASP, it will only be necessary to test the BOP equipment to a maximum of 3,000 psi. Following the cementing of the 7-5/8" combination surface / production casing in this well, the BOP stack will be installed and tested to 3,000 psi. The stage collar will then be drilled out and the well cleaned out to PBTD. At that time, the casing will be pressure tested for 30 minutes at a surface pressure of 3,000 psi as well. The 7-5/8" 29.7# L80 BTC-MOD casing to be used has a burst rating of 6,890 psi; 70 % of this burst rating is 4,823 psi. Following the clean out operation with the completion rig, a frac-pack completion will be installed, after which the ESP pump, power cable, heat trace and production tubing would be installed. Page 2 Drillinq Area Risks: Drilling risks in the West Sak 1D-124 (G3) area are limited to lost circulation and potential borehole instability in and below the permafrost formation. Lost circulation will be addressed with lost circulation material (LCM) and reduced circulating rates as needed. Based on previous Drill Site 1D drilling results, 10.0 ppg mud should be more than adequate to control both the Ugnu and West Sak formation pressures without resulting in lost circulation. ARCO has drilled through the West Sak formation many times in nearby Kuparuk wells. For this reason, AAI requests that the requirements listed in 20 AAC 25.033 (e) and 20 AAC 25.061 (a) (pertaining to predicted overpressured strata and seismic refraction / reflection analysis, respectively) be waived for the drilling of West Sak 1D-124 (G3). Well Proximity Risks: The nearest existing well to West Sak 1D-124 (G3)is KRU 1D-05. As designed, the minimum distance between the two wells would be 28' at 300' MD. Annular Pumping Activities: Incidental fluids generated from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface / production casing annulus of an existing well on DS-ID. That annulus will be left with a non-freezing fluid during any extended shut down (>4 hr) in pumping operations. The West Sak 1D-124 (G3) surface casing / production tubing annulus will be filled with diesel and/or non-freezing brine after setting the 2-7/8" production tubing and prior to the completion rig moving off of the well. TAB, 11/11/97, Rev. 2 Page 3 C~ot~ ~ ~ For: T McKAY Dote p~atted : 25-0ct-97 Plot Reference is W$ 10-124/(;5 Version ~3. Coord;notes ore ;n feet reference slot ~124. T~e V~Hicel 0epths ere ref~ence ~KB (Pork~ ~245) 3OO 3O0 600 RKB ELEVATION: 111' sk Ind. 900 1200 1500 1800 2i00 2400 2700 3000 3300 360O 39OO 4200 <- West (feet) 2200 2000 1800 1600 1400 1200 1000 800 600 400 200 0 200 I I I I I I I I I I I I I I I I I I I I I I I I 200 SURFACE LOCATION 271' FNL, 599' FEL I SEC.23, TllN, RIOE I -~ ~oe t~ ~-~ TARG~ LOCATION: ' f~ '~% I 816' FNL, 2529' FEE ] 800 % Ce, %~ I SEC. 23, T11N, RIOE I ¢~meo~ eDz TARGET z ~o -'~- WD=3723 % %~ TMD=4478 e DEP=2005 SOUTH 545 WEST 1930 0 200 :D" 4oo ~ I V 600 254.23 AZIMUTH KOP TVD:900 TMD=900 DEP=0 2005' (TO TARGET) I TD LOCATION: 4.00 I 862' FNL, 2588' FWL , 8.00 SEC. 2.3, T11N, RIOE ~, 2'4.00 DLS: 4.00 deg per 100 ft -- °'~'~N2~U~oB/ PERMAFROST TVD=1631 TMD=1667 DEP=201 X"='~'., ~6.00 ~ 40.00 ~ 44.001985 TMD=2129 DEP=495 MAXIMUM ANGLE 49.14 DEG CS.OO",~BEGJN ANGLE DROP TVD=2847 TMD=5448 DEP=1495 '~4;,7oo'%7/UONU SNDS TVD=2899 TMD=3526 DEP=1551 OLS: 4.00 deg per 100 ft 24.00 ',,, END ANGLE DROP TVD=5440 TMD=4177 DEP=1902 ~T/ W SAK SNDS 1-VB=3581 TMD=4327 DEP=1954 TARGET - W SAK A3 TVD=3723 TMD=4478 DEP=2005 TARGET ANGLE ~/w SA~ SN0S WO:400~ ~=~4 D~-~=2~o~ 20 DEG ~k TD - CSG PT TVD=4189 TMD=4974 DEP=2175 i i i i i i i i i i i I i i I i i I 300 0 300 600 900 1200 1500 1800 21 O0 2400 Vertical Section (feet) -> Azimuth 254.23 with reference 0.00 N, 0.00 E from slot //124 ~,,ot~ w,~,:~ For: T McKAY ~te p~otted : 25-Oct-fl7 Plot Reference is ~S 1D-12~/G5 Version ~3. Co~d;notes ore ;n ~eet reference s~ot ~124. Verticel Depths ore ref~ence ~6 (Pork~ ~245). 320 280 240 200 160 120 80 4O 120 160 2O0 24O 280 320 360 400 IARCO Alaska, In -ii l Structure : Pad 1D Well: 6,5 Field : Kuparuk River Unit Location : North Slope, <- West (feet) 560 520 480 440 400 360 320 280 240 200 160 120 80 40 0 40 80 I I I I I I t I I I I I I I I I I I I I I I I I I I t I I I t 2400 2300 C~ 2200 2100 2000 ~ 1900 ~ 1800 1700 1600 1500 ~~~'~.900 //'1.300 1900.=.- 2000,,-- .... - I I I I I I I ] I 560 520 480 440 400 1700.,- 1800.,,.- 9900 2000/ / 2100~ 22O0// / 2300/ __.~1 000 13oo~.,¢ 1400..~ ....... / 1500.,,. ....... ,, 1600.~ ............ 24-00/" / / ,, 2500/ 4~900 , '%,1200 ,, x. 1.300 ,,,, ..... ~-x,,,X 14oo / 1500 /' / ,-'"'1000 ~,~0 / 1 O0 ...~ ./ 2700g/ /' ,,-' ..-- 2aoo/.'~oo/fzoo ~"~ ~," ,," / /900 ?' "' 900/~-- ~900 1200 ,,.¢ ,,.- ,'/'~'1400 ,,.'/ L~¥o 1100/ ,o~-',,/',,,,,, .," ¢/3~fl0 120~ ," ,,'.,'15oo / / ~9oo · //," / i ~--~V2..9oo ." /JlO0 //~300 j1100 u:z~2300 ,,,,'/ j ~17' ,/zzoo ~4oo (~" 1~00(~ .... I I I I I I I i I I J I i I I 360 320 280 240 200 160 120 80 40 0 40 80 <- West (feet) 320 280 240 2OO 16O 120 80 40 120 160 20O 24O 28O 32O 36O 4OO A~CO Alaska, Inc. Pad 1D G3 slot #124 Kuparuk River Unit North Slope, Alaska 3-D MINIMUM DISTANCE CLEARANCE REPORT by Baker Hughes INTEQ Your ref : WS 1D-124/G3 Version #3 Our ref : prop2202 License : Date printed : 23-0ct-97 Date created : 16-Apr-97 Last revised : 22-Oct-97 Field is centred on nT0 16 18.576,w150 5 56.536 Structure is centred on nT0 18 1.316,w149 30 18.908 Slot location is nT0 17 58.651,w149 30 36.370 Slot Grid coordinates are N 5959393.696, E 560490.163 Slot local coordinates are 271.00 S 599.00 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Report is limited to clearances less than 500 feet DECREASING CLEAR~ANCES of less than 1000 feet are indicated by an asterisk, e.g. 487.4* Object wellpath PGMS <0-8365'>,,1,Pad 1D TOTCO Sur~;ey,,WS-8,Pad 1D PGMS <O-8930'>,,5,Pad 1D PGMS <O-7502'>,,4,Pad 1D PGMS <O-8070'>,,3,Pad 1D MSS <3311-8200'>,,7,Pad 1D PGMS <O-8610'>,,6,Pad 1D PGMS <0-9783'>,,2,Pad 1D WS 1D-129/J3 Version #3,,J3,Pad 1D WS 1D-130/H4 Version #4,,H4,Pad 1D WS 1D-135/G7 Version #4,,GT,Pad 1D WS 1D-121/G5 Version #3,,GS,Pad 1D WS 1D-133/J5 Version #4,,J5,Pad 1D WS 1D-106/D6 Vers.#3,,D6,Pad 1D WS 1D-109/D4 Vets. #2,,D4,Pad 1D WS 1D-119/F4 Vers.#3,,F4,Pad 1D WS 1D-120/F6 Vets. #3,,F6,Pad 1D WS 1D-118/E5 Version #4,,ES,Pad 1D WS 1D-105/C7 Version #4,,CT,Pad 1D WS 1D-115/E3 Version #4,,E3,Pad 1D WS 1D-117/E7 Version #4,,ET,Pad 1D Closest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging from M.D. 4-Aug-92 507. 16-Oct-96 315. 4-Aug-92 27 4-Aug-92 147 4-Aug-92 268 4-Aug-92 212 4-Aug-92 92 4-Aug-92 387 22-Oct-97 120 9-Oct-97 135 22-0ct-97 255 22-Oct-97 90 22-Oct-97 180 8-Oct-97 375 8-Oct-97 330 6-Oct-97 120 6-Oct-97 105 22-0ct-97 165 22-0ct-97 405 22-0ct-97 210 22-Oct-97 180 6 600.0 3 1375.0 5 300.0 I 720.0 0 20.0 0 440.0 0 20.0 8 420.0 0 300.0 0 600.0 0 780.0 0 900.0 0 280.0 0 900.0 0 380.0 0 900.0 0 900.0 0 900.0 0 380.0 0 280.0 0 380.0 925.0 1375.0 300.0 720.0 860.0 440.0 1050.0 420.0 4973 6 600 0 780 0 900 0 280 0 900 0 380 0 900 0 900 0 900 0 380 0 280 0 380 0 West Sak 1D-124 (G3) Proposed comPletion Diagram Four (4) Stage Frac-Pack 2-7/8" Production Tubing 16" Conductor Casing @ 80' Raychem Heat Trace (through permafrost) Weatherford Gemoco 754HO 7-5/8" DV Stage Collar Stnd. Grade BTC Threads (set +/- 200' TVD below permafrost) Power Cable for ESP Centriiift Camco 2-7/8" Gas Lift Mandrel with 1" side pocket Arctic Lift 3500 psi Shear circulating valve pre-loaded in GLM (circulate well for freeze protection purposes) ESP Pump Section Centrilift ESP Gearbox Centrilift ESP Motor Section Centrilift D Sand Frac-Pack Assembly with Screen Baker Oil Tools B + A4 Sands Frac-Pack Assembly with Screen Baker OII Tools A3 Sand Frac-Pack Assembly with Screen Baker Oil Tools A2 Sand Frac-Pack Assembly with Screen Baker Oil Tools 7-5/8" Combination Surface/Production Casing, 29.7# L-80 BTC-MOD (Cemented to Surface) ARCO Alaska, Inc. TAB, 11/11/97, Rev. 1 KUPARUK RIVER UNIT-WEST sA-~: OPERATIONS 20" DIVERTER SCHEMATIC l I L__ 4 ~,j_~-,_,-~.-_,-.~ 3 DO NOT SHUT IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES. MAINTENAN(~E ~, OPERATION UPON INITIAL INSTALLATION: · CLOSE VALVE AND FILL PREVENTER WITH WATER TO ENSURE NO LEAKS. · CLOSE PREVENTER TO VERIFY OPERATION AND THAT THE VALVE OPENS IMMEDIATELY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN VALVE TO ACHIEVE DIVERSION. ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) 1. 16"CONDUCTOR. 2. SLIP-ON WELD STARTING HEAD. 3. DIVERTER ASSEMBLY WITH ONE 2-1/16"- 2000 PSI BALL VALVE. 4. 20"- 2000 PSI DRILLING SPOOL WITH ONE 16" OUTLET. 5. ONE 16" HCR KNIFE VALVE WITH 16" DIVERTER LINE. THE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. DIVERTER LINE WILL BE PLACED FOR OPTIMUM DISPERSION IN PREVAILING WIND CONDITIONS. 6. 20"- 2000 PSI ANNULAR PREVENTER. TWM, 9/15/97 I I 13 5/8" 5000 PSI BOP STACK West Sak Operations - Producer Wells ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2_ ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH WATER. 2 CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 3 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 3 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILLAND CHOKE LINE VALVES. 6 CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 7. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. CONTINUE TESTING ALL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TESTAS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOTA FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMS AND CLOSE BO3-FOM PIPE RAMS. TEST BOTTOM RAMS TO 250 PSI AND 3000 PSI FOR 3 MINUTES. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 3 MINUTES. BLEED TO ZERO PSI. 10. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI FOR 3 MINUTES. 12_ TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. VBRS WILL ACCOMODATE 3-1/2" TO 6" OR 4-1/2" TO 7" PIPE ODS AS APPROPRIATE. 1. 16"- STARTING HEAD 2. 11" - 5000 PSI HORIZONTAL TUBING HEAr., 3. 11" 5000 PSI X 13-5/8" 5000 PSI DOUBLE STUDDED ADAPTER/SPACER SPOOL 4. 13.5/8" - 5000 PSI X 13-5/8" - 5000 PSI SPACER SPOOL 5. 13-5/8" - 5000 PSI PIPE RAMS 6. 13-5/8" - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 7. 13-5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 8. 13-5/8" -5000 PSI ANNULAR TWM, 9/22/97 ~00~ Pit C~ 106 21 · ~ ~e ~ 2 2 ~ 14.13 ~ , ' ,,~ ~ ~CINI TY MAP ~ ~ ~ 117 I i ~ ~8 ~ 4 I ~ SCALE: I" = 1 MILE 119 ~ 120 121 i I ~ 6 ~ ~ ~29 ~ 135 , i ~ o~ LEGEND si[ SHE~ ~ 2 FOR NOTES ~D LO~TION INFOR~TION 0 EXISDNG CONDUCTORS ~ LOUNSBURY · NEW CONDUCTOR LOCA~ON~'"'~/~ & ASSOCIATES, INC. ~EA' 1D ~ULE XX UNIT' D1 J~ DroLL S~ ~-D A O0 · '--~-~mm~m, [nc, ~ ~s~ s~ .H~S~ ~ - ~ CO. OUC~O.S AS-BUILT CADD FmLE NO.I [ DRA~NO NO: m~T= [~v: LK~04~O 9/02/g7 CEA-D1DX-6104D10 ~ w 2 2 REVt 2.a, TE BY I CK j APP I ~ DESCRIPTION 1 i g/02/g7 AJR I PC I J AS-BUILT PER KSB~ K97082ACS IV 0 TES 1. COORDINATES SHOWN ARE A.S.P. ZONE 4, N.A.D. 27. [LEVA I'IONS SHOWN ARE BRITISH PETROLEUM MEAN SEA LEVEL. ALL D/STANCES SHOWN ARE TRUE. 2. £ASIS OF LOCATIONS AND ELEVATIONS ARE D.S. l-O ~,fONUMENTS PER LHD AND ASSOCIATES. J. CONDUCTORS ARE LOCATED WITHIN PROTRACTED SECTIONS 14 & 23. TOWIVSHIP 11 NORTH. RANGE 10 EAST, U.M. 4. DA TE OF SURVEYS: 8/25, 29 & 50/97. FIELD BK L97-24, pp. 32 - 45, 68 - 7J. 5. DRILL SITE l-O GRID NORTH IS ROTATED 00' 01' 05" '~EST FROM A,S.P. ZONE 4 GRID NORTH, 6, SEE DRAWING NSK-3.5-1 FOR AS-BUILT LOCATIONS OF CONOUCTORS //1 THROUGH ifS. iREV] OATE I 9Y i =,;K I APP I DESCRIPTION 2 !9/17/97, A JR, 'Pc AS-8UILT PER KSB¢ K97082ACS I WEST SAK- 1 THIS SURVEY VICINITY MAP SCALE: I" = I MILE Well SEC. SEC. PAD O. G. No. ,y, A.S.P. s 'X' LA TI TUDE L ONGI TUDE L~,~ L~,J~ ELEV. ELEV. S~.c. 14, T. 11 N., R. 10 E. F,S.L.F.E.L. 105 5,959,798,99 560,490.57 70' 18' 02,657' 149' 30' 36.265" 134' 595' 70.5' 62,0' 106 5,959,768.93 560,490.67 70' 18' 02,341" 149' $0' J6.268" 104' 595' 70.4' 62.3' 109 5,959,723.89 560,490.60 70' 18' 01.898" 149' 30' 36.280" 59' 596' 70.4' 62.7' S;c. 23, T. 11 N., R. IO £. F.N,L,FE.L.~ 115 5,959,603.93 560,490.68 70° 18' .00.?18' 149' 30' 36.$06" 61' 597' 70.4' 63.4' 117 5,959,573.95 560,490,65 70' 18' 00,423' I49' 30' 36.314" 91' 597' 70.4' 65.4' 118 5,959,558.95 560,490.68 70' 18' 00.276' I49' 30' 36.316' 106' 597' 70.4' 63,4' 119 5,959,513.86 560,490.72 70' I7' 59,832' 149' 30' 36.326' 151' 598' 70.6' 66.0' 120 5,959,499.01 560,490,77 70' 17' 59.686' 149' 30' 36,327' 166' 598' 70.6' 66.0' 121 5,959,483.89 560,490.67 70' 17' 59.538' 149' 30' 36.335' 18I' 598' 70.5' 66.0 124 5,959,393.96 560,490,70 70' 17' 58.653' I49' ,70' 36,$55' 271' 599' 70.$' 65.0' 129 5,959,273.92 560,490.79 70' 17' 57.472' 149' 30' 36,380' 391' 600' 70.3' 6&2' I$0 5,959,259,09 560,490.81 70' 17' 57.326' 149' 30' 36.383' 406' 600' 70.5' 68.2' 133 5,959,213.89 560,490.68 70' 17' 56,882' 149' 30' 36,397' 451' 600' 70,4' 69.0' 135 5,959,139.02 560,490.80 70' 17' 56. I46' 149' 30' $6.4;2' 526' 60I' 70.5' 69.4' SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT i AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLA T REPRESENTS A SURVEY DONE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF AUGUST $0, 1997. ARCO Alaska, Inc. LOUNSBURY & ASSOCIATES, INC. E,~tNEERS PLANNERS SURVEYORS AREA' 1D MODULE' XX DRILL SITE 1-D CADD FILE "0- I I ORAW1NG LK610410 9//02/97 UNIT- D1 NO: WEST SAK PHASE I - WELL CONDUCTORS AS-BUILT CEA-D1DX-6104D10 ]SI'I£ET:2 ~ 2 ]~ ARCO Alaska, Inc. Kuparuk Drillsite Development Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 265-6206 Michael Zanghi Supervisor November 12, 1997 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 (907) 279-1433 Re: Application for Permit to Drill ~.?~!;~:~. ~ ~ ~ ;~ ~,r, ~ m~:~ : ~ : '~:~ West Sak 1 D-124 (G3) ,-':~:~:,':i':.:i'~.;: '~r West Sak Phase lA Development Well, Kuparuk River Unit Dear Sirs: ARCO Alaska, Inc. hereby applies for a Permit to Drill an onshore development well to the West Sak interval from 1D pad in the Kuparuk River Unit ("KRU"). The well is designed to penetrate and develop the production potential of the West Sak sands in the vicinity of 1D pad. The well is designed as a producer well using a frac-pack completion technique for reservoir stimulation and sand control purposes. Please find attached information as required by 20 AAC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1) Form 10-401 Application for Permit to Drill per 20 AAC 25.005 (a). 2) Fee of $100 payable to the State of Alaska per 20 AAC 25.005 (c) (1). 3) A directional plat showing the surface and bottomhole locations proposed for the well per 20 AAC 25.005 (c) (2). Note the 40 acre spacing requirements detailed in ARCO's testimony for West Sak Pool Rules governing the West Sak development project. 4) Directional plots and proximity calculations in accordance with the requirements of 20 AAC 25.050. 5) Diagrams and descriptions of the BOP and diverter equipment to be used as required by 20 AAC 25.035 (a) (1) and (b). Note that due to the pressures expected in the West Sak sands, ARCO proposes to test the 5000 psi BOP equipment to a maximum of 3000 psi, pending AOGCC approval per this letter and APD. Please note that due to the large number of KRU wells which have penetrated the West Sak sands in this area, ARCO has a clear understanding of the formation pressures to be encountered. As a result, no overpressured strata is expected in this area. There are also no shallow hazards expected at WS 1D- 124 (G3), such as shallow gas. ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ~ There have been eight (8) Kuparuk wells drilled from KRU 1D pad, and no occurrences of shallow gas or other hazards have been observed. There is a gas sand at approximately 2,100' TVD which is present, but has not caused any past problems in the existing wells which penetrated this sand using a diverter system only. An exception to the requirements set out by 20 AAC 25.033 (e) and 25.061 (a) are hereby requested for this APD because of this regional experience. A prediction of the maximum downhole and surface pressures which may be encountered however are included in this APD per 20 AAC 25.035 (d) (2). 6) A complete proposed casing and cementing program is attached as per 20 AAC 25.030. A wellbore schematic is also attached visually depicting the proposed well and completion design. 7) The drilling fluid program, in addition to the requirements set forth in 20 AAC 25.033 are attached in this APD package. 8) A copy of the proposed drilling program, including a request for approval of annular pumping operations is attached. 9) Also note that ARCO does not anticipate the presence of H2S in the formations to be encountered in this well. However, there will be H2S monitoring equipment functioning on the rigs as is the standard operating procedure in the Kuparuk River Unit drilling operation. 10) Please note that because of the large volume of regional information available in this area, ARCO considers this well to be a development well, and as such, no mudlogging operations such as type log generation and sample catching are planned. An exception to the requirements detailed in 20 AAC 25.005 (c) (8) is thus requested. Please note that the anticipated spud date for this well is November 24, 1997. If you have any questions or require further information, please contact Tom Brockway at (907) 263- 4135 or Tom McKay at (907) 265-6890. Operations Drilling Engineer Attachments: cc: West Sak 1D-124 (G3) Well File Tom McKay ATO-1202 Keith Lynch ATO-1228 Ike Bellaci ATO-1260 Cliff Crabtree NSK6 ARCO Alaska, Inc. Kuparuk Drillsite Development Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 265-6206 Michael Zanghi Supervisor November 12, 1997 ORIGINAL Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 (907) 279-1433 Re: Application for Permit to Drill West Sak 1 D-124 (G3) ,'-, West Sak Phase lA Development Well, Kuparuk River Unit Dear Sirs: ARCO Alaska, Inc. hereby applies for a Permit to Drill an onshore development well to the West Sak interval from 1D pad in the Kuparuk River Unit ("KRU"). The well is designed to penetrate and develop the production potential of the West Sak sands in the vicinity of 1 D pad. The well is designed as a producer well using a frac-pack completion technique for reservoir stimulation and sand control purposes. Please find attached information as required by 20 AAC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1) Form 10-401 Application for Permit to Drill per 20 AAC 25.005 (a). 2) Fee of $100 payable to the State of Alaska per 20 AAC 25.005 (c) (1). 3) A directional plat showing the surface and bottomhole locations proposed for the well per 20 AAC 25.005 (c) (2). Note the 40 acre spacing requirements detailed in ARCO's testimony for West Sak Pool Rules governing the West Sak development project. 4) Directional plots and proximity calculations in accordance with the requirements of 20 AAC 25.050. 5) Diagrams and descriptions of the BOP and diverter equipment to be used as required by 20 AAC 25.035 (a) (1) and (b). Note that due to the pressures expected in the West Sak sands, ARCO proposes to test the 5000 psi BOP equipment to a maximum of 3000 psi, pending AOGCC approval per this letter and APD. Please note that due to the large number of KRU wells which have penetrated the West Sak sands in this area, ARCO has a clear understanding of the formation pressures to be encountered. As a result, no overpressured strata is expected in this area. There are also no shallow hazards expected at WS 1D- 124 (G3), such as shallow gas. ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany There have been eight (8) Kuparuk wells drilled from KRU 1D pad, and no occurrences of shallow gas or other hazards have been observed. There is a gas sand at approximately 2,100' TVD which is present, but has not caused any past problems in the existing wells which penetrated this sand using a diverter system only. An exception to the requirements set out by 20 AAC 25.033 (e) and 25.061 (a) are hereby requested for this APD because of this regional experience. A prediction of the maximum downhole and surface pressures which may be encountered however are included in this APD per 20 AAC 25.035 (d) (2). 6) A complete proposed casing and cementing program is attached as per 20 AAC 25.030. A wellbore schematic is also attached visually depicting the proposed well and completion design. 7) The drilling fluid program, in addition to the requirements set forth in 20 AAC 25.033 are attached in this APD package. 8) A copy of the proposed drilling program, including a request for approval of annular pumping operations is attached. 9) Also note that ARCO does not anticipate the presence of H2S in the formations to be encountered in this well. However, there will be H2S monitoring equipment functioning on the rigs as is the standard operating procedure in the Kuparuk River Unit drilling operation. 10) Please note that because of the large volume of regional information available in this area, ARCO considers this well to be a development well, and as such, no mudlogging operations such as type log generation and sample catching are planned. An exception to the requirements detailed in 20 AAC 25.005 (c) (8) is thus requested. Please note that the anticipated spud date for this well is November 24, 1997. If you have any questions or require further information, please contact Tom Brockway at (907) 263- 4135 or Tom McKay at (907) 265-6890. Operations Drilling Engineer Attachments: cc: West Sak 1D-124 (G3) Well File Tom McKa¥ ATO-1202 Keith Lynch ATO-1228 Ike Bellaci ATO-1260 Cliff Crabtree NSK6 · WELL PERMIT CHECKLIST COMPANY ~a_~ FIELD & POOL 4/~<::3/v<,.."d;) INIT CLASS _/~¢_~/ ./-<~/' WELL NAME //~) -//.~--. GEOL AREA PROGRAM: exp [] dev~'redrll [] serv [] wellbore seg C ann. disposal para req [] U NIT:/¢ //./'~¢:;',,~ ON/OFF SHORE ADMINISTRATION DATE,/ 1. Permit fee attached ....................... N 2. Lease number appropriate ................... .N 3. Unique well name and number .................. N 4. Well located in a defined pool .................. N 5. Well located proper distance from drilling unit boundary .... N 6. Well located proper distance from other wells .......... N 7. Sufficient acreage available in drilling unit ............ N 8. If deviated, is wellbore plat included ............... N 9. Operator only affected party ................... N 10. Operator has appropriate bond in force ............. N 11. Permit can be issued without conservation order ........ N 12. Permit can be issued without administrative approval ...... N 13. Can permit be approved before 15-day wait ........... N ENGINEERING A<~ DATE "'IT / 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... (~ N 16. CMT vol adequate to circulate on conductor & surf csg ..... N 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... Y. N 22. Adequate wellbore separation proposed ............. N 23. If diverter required, does it meet regulations .......... N 24. Drilling fluid program schematic & equip list adequate ..... N 25. BOPEs, do they meet regulation ................ N 26. BOPE press rating appropriate; test to '~~ psig. N 27. Choke manifold complies w/APl RP-53 (May 84) ........ N 28. Work Will occur without operation shutdown ........... N 29. Is presence of H2S gas probable ................. Y (~) GEOLOGY APPR D T 30. Permit can be issued w/o hydrogen sulfide measures ..... Y N 31. Data presented on potential overpressure zones ....... Y / ,/~,~. 32. Seismic analysis of shallow gas zones ............. z~_ N" .... 33. Seabed condition survey (if off-shore) ............. /Y N 34. Contact name/phone for we,eklyprogress reports ...... / Y N lexptoratory only] REMARKS GEOLOGY: ENGINEERING: COMMISSION' ODH~:~___t RNC~ CO ~ Comments/Instructions: HOWlljt - A:\FORMS\cheklist rev 09/97 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility Thu Jan 22 13:54:13 1998 Reel Header Service name ............. LISTPE Date ..................... 98/01/22 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Tape Header Service name ............. LISTPE Date ..................... 98/01/22 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Scientific Physical EOF Comment Record TAPE HEADER KUPARUK RIVER UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MWD RUN 1 AK-MM-80064 S. BURKHARDT G. WHITLOCK 1D-124 500292283300 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 22-JAN-98 llN 10E !~ .... ' ~ ~'-. £~ o' 271 ':i= '!:.? ~, ,u ..... .00 111.30 70.30 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.875 5047.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUN 1 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4) . 3. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE PHONE CONVERSATION BETWEEN ROB KALISH OF SPERRY-SUN DRILLING SERVICES AND MIKE WERNER OF ARCO ALASKA, INC. ON 19 JANUARY, 1998. 4. THIS WELL REACHED A TOTAL DEPTH (TD) OF 5047'MD, 4262'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/01/22 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipQed curves; all bit runs merged. .5000 DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE FET RPD RPM RPS RPX GR ROP $ START DEPTH STOP DEPTH 121.0 5003.0 121.0 5003.0 121.0 5003.0 121.0 5003.0 121.0 5003.0 121.0 5010.0 122.5 5047.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE $ REMARKS: EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 1 121.0 5047.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ............... ' ....... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD FT/H 4 1 68 GR MWD AAPI 4 1 68 RPM MWD OHMM 4 1 68 RPX MWD OHMM 4 1 68 RPS MWD OHMM 4 1 68 RPD MWD OH/~4 4 1 68 FET MWD HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 2O 6 24 7 28 8 Name Min Max Mean DEPT 121 5047 2584 ROP 18.81gl 644.35 227.315 GR 8.9792 110.746 56.4521 RPM 0.1824 2000 60.7253 RPX 0.423 1033.32 33.8639 RPS 0.5185 2000 40.1499 RPD 0.4021 2000 82.3944 FET 0.1104 3.7031 0.438656 Nsam 9853 9850 9779 9765 9765 9765 9765 9765 First Reading 121 122.5 121 121 121 121 121 121 Last Reading 5047 5047 5010 5003 5003 5003 5003 5003 First Reading For Entire File .......... 121 Last Reading For Entire File ........... 5047 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/01/22 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/01/22 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH FET 121.0 RPD 121.0 RPM 121.0 RPS 121.0 RPX 121.0 GR 121.0 ROP 122.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 5003 0 5OO3 0 5003 0 5003 0 5003 0 5010 0 5047.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: 04-JAN-98 ISC 5.06 CIM 5.46 MEMORY 5047.0 121.0 5047.0 .9 51.3 TOOL NUMBER P0891CRG6 P0891CRG6 9.880 9.9 SPUD MUD 176.90 306.0 8.8 MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 4OO 7.2 7.000 5.400 6.100 3.100 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 1 AAPI 4 1 68 4 2 RPX MWD 1 OH14M 4 1 68 8 3 RPS MWD 1 OHIVfM 4 1 68 12 4 RPM MWD 1 OHMM 4 1 68 16 5 RPD MWD 1 OHMM 4 1 68 20 6 ROP MWD 1 FT/H 4 1 68 24 7 FET MWD 1 HOUR 4 1 68 28 8 36.7 First Name Min Max Mean Nsam Reading DEPT 121 5047 2584 9853 121 GR 8.9792 110.746 56.4521 9779 121 RPX 0.423 1033.32 33.8639 9765 121 RPS 0.5185 2000 40.1499 9765 121 RPM 0.1824 2000 60.7253 9765 121 RPD 0.4021 2000 82.3944 9765 121 ROP 18.8101 644.35 227.315 9850 122.5 FET 0.1104 3.7031 0.438656 9765 121 Last Reading 5047 5010 5003 5003 5003 5003 5047 5003 First Reading For Entire File .......... 121 Last Reading For Entire File ........... 5047 File Trailer Service name ............. STSLIB.002 SIq ~O pu~ OT~T~UeTO$ ~UT~T~M SIq S&S ................. s~ueumzoD N/vION-~N/1 ........... e~e~ ~ee~ ~×e~ TO ...... zequmx uoT~uT~uoD NMONZNFI ................ eurex TeeH S&S ................... uTbTzO ~Y/T0/86 ..................... eq~C seoTA~eS IeoTuqoa~ 5u!~!z~ SI~ S~S ................. s~ueuauoo NMONDINfl ........... ~ureN ~d~ ~xeN I0 ...... zsqumN uo~nu~uoD NMON-MNQ ................ ~UreN S~S ................... uTST~O ~E/I0/86 ..................... ~ASIq ............. eureu eoTA=eS ~eTT~ £00'SIqS~S ........... e~eN eIT~ ~XeN Oq ................ edAi eIT~ ~/T0/86 ....... uoT~eue~ ~o e~G 0'0'I ........... zeqmnN uo~szeA
